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Relevant bibliographies by topics / Chemical enhanced oil recovery

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Academic literature on the topic 'Chemical enhanced oil recovery'

Author: Grafiati

Published: 4 June 2021

Last updated: 1 February 2022

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Journal articles on the topic "Chemical enhanced oil recovery"

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Lwisa, Essa Georges. "Chemical Enhanced Oil Recovery." International Journal for Innovation Education and Research 9, no. 6 (2021): 160–72. http://dx.doi.org/10.31686/ijier.vol9.iss6.3160.

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Enhanced Oil Recovery (EOR) techniques are currently one of the top priorities of technological development in the oil industry owing to the increasing demand for oil and gas, which cannot be fulfilled by primary or secondary production methods. The main function of the enhanced oil recovery process is to displace oil in the production wells by the injection of different fluids to supplement the natural energy present in the reservoir. moreover these injecting fluids can alter the reservoir`s properties; for example they can lower the interfacial tension (IFT) between oil and water, alter the rocks` wettability, change the pH value, form emulsions aid in clay migration and reduce the oil viscosity. In this chapter, we will discuss the following methods of chemical enhanced oil recovery: polymer flooding, surfactant flooding, alkaline flooding and smart water flooding. In addition, we will review the merits and demerits of each method and conclude the chapter with our recommendations

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Merchan-Arenas, Diego R., and Cindy Carolina Villabona-Delgado. "Chemical-Enhanced Oil Recovery Using N,N-Dimethylcyclohexylamine on a Colombian Crude Oil." International Journal of Chemical Engineering 2019 (May 2, 2019): 1–10. http://dx.doi.org/10.1155/2019/5241419.

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Oil recovery was improved using the tertiary amine, N,N-dimethylcyclohexylamine (DMCHA), a powerful and promissory switchable solvent, in simulated conditions similar to the Colombian crude oil reserves. Firstly, the Colombian crude oil (CCO) and the soil were characterized completely. Afterwards, an aged crude-rock system was obtained to use DMCHA that gave an oil crude extraction of 80% in our preliminary studies. Thus, a sand-pack column (soil-kaolin, 95 : 5) frame saturated with CCO was used to simulate the conditions, in which DMCHA could recover the oil. After the secondary recovery process, 15.4–33.8% of original oil in place (OOIP) is obtained. Following the injection of DMCHA, the recovery yield rose to 87–97% of OOIP. Finally, 54–60% of DMCHA was recovered and reinjected without affecting its potential in the simulated conditions.

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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.

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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 followed by a mobility buffer such as polymer. The total volume of the polymer solution is typically ~1 PV. This study was conducted to examine the effectiveness of the combination of microbial by-products Bacillus subtilise strain JF-2 bio-surfactant and alcohol in recovering residual oil. It also considered whether bio-surfactant capability could be improved by blending it with non-ionic green surfactant. The study consisted of a phase behaviour study, IFT measurement and core-flooding experiments. In the phase behaviour study, it was found that 0.5% alkyl polyglycosides (APG) and 0.5–1.00% of butanol at 2% NaCl gave stable middle phase micro-emulsion. Non-ionic (APG 264) and anionic (bio-surfactant) mixtures are able to form stable middle phase micro-emulsion. Based on IFT reduction, two low concentrations (40 and 60 mg/l) of JF-2 bio-surfactant were identified where IFT values were low. The bio-surfactant and butanol formulation produced a total ~39.3% of oil initially in place (OIIP).

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Koryakin, F. A., N. Yu Tretyakov, O. B. Abdulla, and V. G. Filippov. "Hydrocarbon saturation determination with the single-well-chemical-tracer-test under laboratory conditions." Oil and Gas Studies, no. 6 (January 15, 2021): 131–43. http://dx.doi.org/10.31660/0445-0108-2020-6-131-143.

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Nowadays the share of hard-to-recover reserves is growing, and to maintain oil production on necessarily level, we need to involve hard-to-recover reserves or to increase oil production efficiency on a brownfields due to enhanced oil recovery. The efficiency of enhanced oil recovery can be estimated by oil saturation reduction. Single-well-chemical-tracer-test (SWCTT) is increasingly used to estimate oil saturation before and after enhanced oil recovery application. To interpret results of SWCTT, reservoir simulation is recommended. Oil saturation has been calculated by SWCTT interpretation with use of reservoir simulator (CMG STARS). Distribution constants has been corrected due to results of real core sample model, and core tests has been successfully simulated. Obtained values of oil saturation corresponds with real oil saturation of samples. Thus, SWCTT as a method of oil saturation estimation shows good results. This method is promising for enhanced oil recovery efficiency estimation.

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Mandal, Ajay. "Chemical flood enhanced oil recovery: a review." International Journal of Oil, Gas and Coal Technology 9, no. 3 (2015): 241. http://dx.doi.org/10.1504/ijogct.2015.069001.

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Hosseini-Nasab, S. M., P. L. J. Zitha, S. A. Mirhaj, and M. Simjoo. "A new chemical-enhanced oil recovery method?" Colloids and Surfaces A: Physicochemical and Engineering Aspects 507 (October 2016): 89–95. http://dx.doi.org/10.1016/j.colsurfa.2016.07.087.

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Machale, Jinesh, Subrata Kumar Majumder, Pallab Ghosh, and Tushar Kanti Sen. "Role of chemical additives and their rheological properties in enhanced oil recovery." Reviews in Chemical Engineering 36, no. 7 (2020): 789–830. http://dx.doi.org/10.1515/revce-2018-0033.

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AbstractA significant amount of oil (i.e. 60–70%) remains trapped in reservoirs after the conventional primary and secondary methods of oil recovery. Enhanced oil recovery (EOR) methods are therefore necessary to recover the major fraction of unrecovered trapped oil from reservoirs to meet the present-day energy demands. The chemical EOR method is one of the promising methods where various chemical additives, such as alkalis, surfactants, polymer, and the combination of all alkali–surfactant–polymer (ASP) or surfactant–polymer (SP) solutions, are injected into the reservoir to improve the displacement and sweep efficiency. Every oil field has different conditions, which imposes new challenges toward alternative but more effective EOR techniques. Among such attractive alternative additives are polymeric surfactants, natural surfactants, nanoparticles, and self-assembled polymer systems for EOR. In this paper, water-soluble chemical additives such as alkalis, surfactants, polymer, and ASP or SP solution for chemical EOR are highlighted. This review also discusses the concepts and techniques related to the chemical methods of EOR, and highlights the rheological properties of the chemicals involved in the efficiency of EOR methods.

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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.

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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 sets of experimental field data from Daqing oil field (PPG conformance control after polymer flooding) and Shengli oil field (PPG-surfactant flooding after polymer flooding) are used to check the reliability of the model. Combination of preformed gel particles, polymers and surfactants due to the deformation, swelling, and physicochemical properties of gel particles can mobilize the trapped oil through the porous media to enhance oil recovery factor by blocking the high permeable channels. As a result, PPG conformance control plays an essential role in oil recovery enhancement. Furthermore, experimental data of PPG/polymer/surfactant flooding in the Shengli field and its comparison with the proposed model indicated that the model and experimental field data are in a good agreement. Consequently, the coupled model of surfactant and PPG flooding after polymer flooding performances has led to more recovery factor rather than the basic chemical recovery techniques.

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Lu, Jun, Pathma Jith Liyanage, Sriram Solairaj, et al. "New surfactant developments for chemical enhanced oil recovery." Journal of Petroleum Science and Engineering 120 (August 2014): 94–101. http://dx.doi.org/10.1016/j.petrol.2014.05.021.

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Sheng, James J. "Formation damage in chemical enhanced oil recovery processes." Asia-Pacific Journal of Chemical Engineering 11, no. 6 (2016): 826–35. http://dx.doi.org/10.1002/apj.2035.

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Dissertations / Theses on the topic "Chemical enhanced oil recovery"

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Bongartz, Dominik. "Chemical kinetic modeling of oxy-fuel combustion of sour gas for enhanced oil recovery." Thesis, Massachusetts Institute of Technology, 2014. http://hdl.handle.net/1721.1/92224.

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Thesis: S.M., Massachusetts Institute of Technology, Department of Mechanical Engineering, 2014.<br>Cataloged from PDF version of thesis.<br>Includes bibliographical references (pages 135-147).<br>Oxy-fuel combustion of sour gas, a mixture of natural gas (primarily methane (CH 4 )), carbon dioxide (CO 2 ), and hydrogen sulfide (H 2 S), could enable the utilization of large natural gas resources, especially when combined with enhanced oil recovery (EOR). Chemical kinetic modeling can help to assess the potential of this approach. In this thesis, a detailed chemical reaction mechanism for oxy-fuel combustion of sour gas has been developed and applied for studying the combustion behavior of sour gas and the design of power cycles with EOR. The reaction mechanism was constructed by combining mechanisms for the oxidation of CH4 and H2S and optimizing the sulfur sub-mechanism. The optimized mechanism was validated against experimental data for oxy-fuel combustion of CH4, oxidation of H2S, and interaction between carbon and sulfur species. Improved overall performance was achieved through the optimization and all important trends were captured in the modeling results. Calculations with the optimized mechanism suggest that increasing H2 S content in the fuel tends to improve flame stability through a lower ignition delay time. Water diluted oxy-fuel combustion leads to higher burning velocities at elevated pressures than CO 2 dilution or air combustion, which also facilitates flame stabilization. In a mixed CH4 and H2S flame, H25 is oxidized completely as CH4 is converted to carbon monoxide (CO). During CO burnout, some highly corrosive sulfur trioxide (SO3 ) is formed. Quenching of SO 3 formation in the combustor can only be achieved at the expense of higher CO emissions. The modeling of a gas turbine cycle showed that oxy-fuel combustion leads to SO 3 concentrations that are one to two orders of magnitude lower than in air combustion and will thus suffer much less from the associated corrosion problems. Slightly fuel-rich operation is most promising for achieving the low CO and oxygen (02) concentrations required for EOR while further minimizing SO 3. Carbon dioxide dilution is better for achiving low 02 in the EOR stream while H20 gives the better combustion efficiency.<br>by Dominik Bongartz.<br>S.M.

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Oduntan, Aderinsola. "The Rheological Study of the Effects of Surfactant and Hydrophilic Bentonite Nano clay on Oil in Water Emulsions for Enhanced Oil Recovery." Thesis, University of Louisiana at Lafayette, 2018. http://pqdtopen.proquest.com/#viewpdf?dispub=10682665.

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<p> In this study, Nano clay suspo-emulsions rheologically characterized for the application in enhanced oil recovery. The impact of Bentonite Nano clay particles on the rheological properties of paraffin oil-water emulsion prepared using CTAB (a cationic surfactant) and DOSS (anionic surfactant), commonly used in petroleum and industrial applications as emulsifiers were investigated. </p><p> Surface tension and Rheological measurements of the two surfactants were determined using concentrations ranging from 10<sup>−6</sup> moles/liter to 10<sup>−1</sup>moles/liter (concentrations above and below the critical micelle concentration). </p><p> The bulk rheological behavior of emulsions was characterized without and with the addition of Bentonite Nano clay particles through rheological measurements. The emulsions were tested with varying concentrations of CTAB and DOSS ranging from 10<sup>−6</sup> moles/liter to 10<sup> −1</sup> moles/liter. These bulk rheology tests included shear rate sweeps and oscillatory tests to determine the viscosity, yield stress, critical stress, storage, and loss modulus. For these rheological tests, the oil-water ratio was varied ranging from 10% v/v to 90% v/v to determine how these results might differ in different emulsion systems. The rheological result for 10/90 % v/v emulsion, prepared with CTAB and DOSS (with and without the addition of Bentonite Nano clay particles) was analyzed. The addition of Bentonite Nano clay led to an increase in the storage and loss modulus of the emulsions. </p><p> Interfacial shear rheology tests were further carried out in two runs to determine the strength and mechanical properties of the film at the oil-water interface. By varying concentrations of CTAB and DOSS from 10<sup>−6 </sup> moles/liter to 10<sup>−1</sup>moles/liter in the first run and adding Bentonite Nano clay in the second run, interfacial viscosity measured at four different temperatures and the interfacial storage modulus measured at room temperature was obtained. A zero-loss modulus was recorded for each run confirming that the oil-water interface is more elastic (solid-like). </p><p>

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Atthawutthisin, Natthaporn. "Numerical Simulation of Low Salinity Water Flooding Assisted with Chemical Flooding for Enhanced Oil Recovery." Thesis, Norges teknisk-naturvitenskapelige universitet, Institutt for petroleumsteknologi og anvendt geofysikk, 2012. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-19113.

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World proved oil reserve gradually decreases due to the increase production but decrease new field discovery. The focus on enhance oil recovery from the existing fields has become more interesting in the recent years. Since waterflooding has been used in practices in secondary recovery phase for long time ago, the low salinity waterflooding is possible to apply as tertiary recovery phase. Another effective enhance oil recovery method is chemical flooding especially, nowadays, when the price of chemical is not a big issue compared to oil price. Both low salinity and chemical flooding method have been trialed and success in laboratory studies and some field tests. Moreover the salinity sensitivity on chemical flooding has been studied and both positive and negative results were proposed. Because new technology has been developing day by day in order to get higher oil recovery, the new technology as the combination of low salinity waterflooding and chemical flooding has been studied in this report. In this thesis, the literature of low salinity water flooding, alkaline flooding, surfactant flooding, polymer flooding and alkaline-surfactant-polymer flooding (ASP) have been reviewed. The mechanisms of each method that affect to oil recovery and salinity sensitivity on each chemical flooding method have been summarized. All of those studies showed the benefit of chemical to the low salinity water flooding. the result of literature reviews has turned to the numerical simulation part.The simulation has been carried out on a 3 dimensional synthetic model by using Eclipse 100 as the simulator. The model is heterogeneous with patterns variation in permeability and porosity. The effect of low salinity in water flooding, alkaline flooding, surfactant flooding, polymer flooding and ASP flooding have been observed in many aspects.The main role of low salinity effect in water flooding is wettability changing from oil-wet to water-wet. The low salinity water in the first water flooding phase give the positive effect but not much different compared to overall recovery. The low salinity in chemical solution influences an additional oil recovery in all combinations. Mainly, low salinity increases polymer solution viscosity that can improve sweep efficiency of polymer flooding. In alkaline flooding and surfactant flooding, the salinity is need to be optimized to optimum salinity condition corresponding to optimum alkaline concentration and surfactant concentration, where creates the lowest IFT. The range of secondary flooding for alkaline and surfactant flooding is when they reach the optimum concentration. In case of polymer, the viscous polymer solution can impact longer as the polymer injection range. In term of low salinity in tertiary water flooding, it influences better oil recovery than high salinity water flooding. Therefore, it can be concluded that low salinity water flooding gives a positive effect to overall result when combined with chemical flooding. The recommendations are also available for further study.

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Tang, Huiling. "Rheological Measurements and Core Flood Data Analysis in Support of Chemical Enhanced Oil Recovery Formulation Design." Thesis, Purdue University, 2017. http://pqdtopen.proquest.com/#viewpdf?dispub=10618534.

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<p> This research involved rheological measurements and the analysis of core flood test data in support of the design of a formulation for Chemical Enhanced Oil Recovery (cEOR) at the Pioneer Rock Hill reservoir, a site characterized by relatively low formation brine salinity and temperature. Extensive and systematic rheological measurements identified viscosity values and rheological behaviors of different polymers, surfactants and polymer-surfactant solutions over a range of concentrations, salinities, and temperatures relevant to the targeted field conditions. The results were used to support formulation design in combination with phase behavior studies and interfacial tension measurements, provide information relevant to in-tank mixing/pumping operations, and maximize sweep efficiency and mobility control in the core flood tests. Further rheological measurements were conducted on the primary surfactant, Petrostep<sup>® </sup> S13D, over a broad range of concentrations in both deionized water and two synthetic brines, up to neat solution. The results of these tests indicate that different structures (micellar solution, hexagonal liquid crystal, and lamellar liquid crystal) form at different concentrations, supporting SAXS observations performed by another research group. </p><p> In a separate effort, data obtained from core flood tests conducted in the Purdue EOR laboratory to evaluate and optimize formulations, were collected and organized. Five performance parameters: recovery factor in terms of %ROIP, oil saturation after chemical flood (S<sub>orc</sub>), maximum injection pressure during chemical flood, surfactant sorption, and total injectant cost, were selected to evaluate test efficiency, based on technical and economic feasibility. Performance analysis of the core flood data and comparison with data from the literature show average to very good performance of the Purdue core flood tests.</p><p>

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Rosli, Nor Roslina. "The Effect of Oxygen in Sweet Corrosion of Carbon Steel for Enhanced Oil Recovery Applications." Ohio University / OhioLINK, 2015. http://rave.ohiolink.edu/etdc/view?acc_num=ohiou1448974434.

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Dieterichs, Christin. "Laboratory Investigations on the Applicability of Triphenoxymethanes as a New Class of Viscoelastic Solutions in Chemical Enhanced Oil Recovery." Doctoral thesis, Technische Universitaet Bergakademie Freiberg Universitaetsbibliothek "Georgius Agricola", 2018. http://nbn-resolving.de/urn:nbn:de:bsz:105-qucosa-234749.

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Even in times of renewable energy revolution fossil fuels will play a major role in energy supply, transportation, and chemical industry. Therefore, increasing demand for crude oil will still have to be met in the next decades by developing new oil re-serves. To cope with this challenge, companies and researchers are constantly seeking for new methods to increase the recovery factor of oil fields. For that reason, many enhanced oil recovery (EOR) methods have been developed and applied in the field. EOR methods alter the physico-chemical conditions inside the reservoir. One possibility to achieve this is to inject an aqueous solution containing special chemicals into the oil-bearing zone. Polymers, for example, increase the viscosity of the injected water and hence improve the displacement of the oil to the production well. The injection of surfactant solutions results in reduced capillary forces, which retain the oil in the pores of the reservoir. Some surfactants form viscoelastic solutions under certain conditions. The possibil-ity to apply those solutions for enhanced oil recovery has been investigated by some authors in the last years in low salinity brines. Reservoir brines, however, often contain high salt concentrations, which have detrimental effects on the properties of many chemical solutions applied for EOR operations. The Triphenoxymethane derivatives, which were the subject of study in this thesis, form viscoelastic solutions even in highly saline brines. The aim of this thesis was to investigate the efficiency and the mode-of-action of this new class of chemical EOR molecules with respect to oil mobilization in porous media.

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Alonso, Benito Gerard. "Models and Computational Methods Applied to Industrial Gas Separation Processes and Enhanced Oil Recovery." Doctoral thesis, Universitat de Barcelona, 2019. http://hdl.handle.net/10803/668115.

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Two main topics are treated in this doctoral thesis from a theoretical and computational point of view: the gas capture and separation from post-combustion flue gases, and the enhanced oil recovery from oil reservoirs. The first topic evaluates the separation of CO2 using three different materials. First, several zeolites from the Faujasite family are studied with a combination of Density Functional Theory (DFT) and Monte Carlo methods. The former is employed to understand the driving mechanisms of adsorption, whereas the latter served to assess the separation of CO2 from a flue gas formed by a ternary mixture of CO2, N2 and O2. Second, the adsorption of CO2, N2 and SO2 into Mg-MOF-74 obtained through DFT calculations is presented to determine the most fundamental gas/MOF interactions. The results are then coupled to a Langmuir isotherm model to derive the macroscopic adsorption isotherms of the three gases in Mg-MOF-74. Finally, the absorption of CO2 and SO2 into three different phosphonium-based Ionic Liquids (ILs) is addressed by using the soft-SAFT equation of state and the COSMO-RS model. From the calculated adsorption/absorption isotherms several properties are obtained, such as the purity in the recovered gas, the working capacity of the materials and their selectivity to capture CO2 in the presence of other contaminant species. The main results obtained from this part of the thesis reveal that the cations of microporous materials are very strong sites of absorption for polar gases (i.e., the Na+ cations in Faujasites or the Mg2+ cations in Mg-MOF-74). This feature makes them very good candidates for CO2 capture, but they can be easily poisoned by other polar gases such as SO2. For this reason, it is highly recommended to desulphurize the flue gas before using any of these adsorbents. Similarly, ILs have higher affinity for SO2 than for CO2. However, the gas/IL interactions are significantly weaker, so they do not become poisoned by SO2. This fact implies that SO2 can be captured and separated from the flue gas by using a phosphonium-based IL. The second topic describes via Molecular Dynamics simulations the interactions of several model oils with different rocks and brines. The obtained insight can be applied in better understanding the interactions of the species present at oil reservoirs, with direct application in enhanced oil recovery processes. To that end, two wettability indicators are monitored to determine the potential recovery of the model oils. First, the oil/water interfacial tension (IFT) under different conditions of temperature, pressure and salinity (i.e., from pure water to 2.0 mol/kg of NaCl or CaCl2). And second, the oil/water/rock contact angle (CA) on calcite (10-14) and kaolinite (001) also as a function of salinity (i.e., from pure water to 2.0 mol/kg of NaCl or CaCl2). The different model oils are built with molecules of different chemical nature representing the Saturate/Aromatic/Resin/Asphaltene (SARA) fractionation model. In a final stage of the doctoral thesis the effect of non-ionic surfactants at the oil/brine IFT is also included. The main results obtained show that the most polar components of oil migrate to the oil/water interface and reduce the IFT. However, the same compounds feel attracted to the rock, who increase the CA and hamper the oil recovery. Some of these interactions are affected by the presence of salt. Specifically, if a water layer is formed between the oil and the rock in a reservoir, electrolytes can diffuse into it and attract the polar components of oil, ultimately increasing the CA. Finally, cations can be attracted to the oil/water interface due to salt/surfactant interactions. Both species interact synergistically to modify their orientation/distribution at the interface and reduce the oil/water IFT.<br>En aquesta tesi doctoral s’han tractat dos temes principals des d’una perspectiva teòrica i computacional: la captura i separació de gasos de post-combustió, i la recuperació millorada de petroli. El primer tema avalua la separació de CO2 utilitzant tres materials diferents. Primer, s’han estudiat diverses zeolites de la família de les Faujasites amb una combinació de teoria del funcional de la densitat (TFD) i mètodes Monte Carlo per entendre els mecanismes d’adsorció separació de CO2 d’una mescla ternària que conté CO2, N2 i O2. Seguidament, s’ha presentat un estudi TFD d’adsorció de CO2, N2 i SO2 en Mg-MOF-74 per determinar les interaccions fonamentals del MOF amb cada gas. Aquesta informació s’ha acoblat a un model d’isoterma de Langmuir per tal de derivar les isotermes d’adsorció macroscòpiques dels tres gasos en Mg-MOF-74. Finalment, s’ha analitzat l’absorció de CO2 i SO2 en tres Líquids Iònics (LIs) basats en fosfoni mitjançant l’equació d’estat soft-SAFT i el model COSMO-RS. D’altra banda, el segon tema descriu les interaccions de diferents models de petroli amb roques i salmorres, via simulacions de Dinàmica Molecular. El coneixement adquirit en aquesta part de la tesi doctoral es pot aplicar directament a la recuperació millorada de petroli i per entendre millor les interaccions de les espècies presents als pous. Amb aquesta finalitat, s’han controlat dos indicadors de la mullabilitat per determinar la recuperació potencial d’aquests models de petroli. Primer la tensió interfacial (TIF) oli/aigua sota diferents condicions de temperatura, pressió i salinitat (des d’aigua pura a 2.0 mol/kg de NaCl o CaCl2). I segon, l’angle de contacte oli/aigua/roca en calcita (10-14) i caolinita (001) en funció de la salinitat (des d’aigua pura a 2.0 mol/kg de NaCl o CaCl2). Els diferents models de petroli s’han construït amb molècules de diferent naturalesa química representant el model de fraccionament Saturat/Aromàtic/Resina/Asfaltè (SARA). En una etapa final de la tesi doctoral s’ha inclòs l’efecte en la TIF induïda pels surfactants no-iònics a la interfase oli/salmorra.

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Födisch, Hendrik [Verfasser], and L. [Akademischer Betreuer] Ganzer. "Investigation of chemical enhanced oil recovery core flooding processes with special focus on rock-fluid interactions / Hendrik Födisch ; Betreuer: L. Ganzer." Clausthal-Zellerfeld : Technische Universität Clausthal, 2019. http://d-nb.info/1231363118/34.

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Dieterichs, Christin [Verfasser], Moh\'d [Akademischer Betreuer] Amro, Moh\'d [Gutachter] Amro, Ingebret [Gutachter] Fjelde, and Foppe [Gutachter] Visser. "Laboratory Investigations on the Applicability of Triphenoxymethanes as a New Class of Viscoelastic Solutions in Chemical Enhanced Oil Recovery / Christin Dieterichs ; Gutachter: Moh\'d Amro, Ingebret Fjelde, Foppe Visser ; Betreuer: Moh\'d Amro." Freiberg : Technische Universitaet Bergakademie Freiberg Universitaetsbibliothek "Georgius Agricola", 2018. http://d-nb.info/1221070274/34.

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Jia, Ru. "Mechanisms of Microbiologically Influenced Corrosion Caused by Corrosive Biofilms and its Mitigation Using Enhanced Biocide Treatment." Ohio University / OhioLINK, 2018. http://rave.ohiolink.edu/etdc/view?acc_num=ohiou1541425677541433.

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Books on the topic "Chemical enhanced oil recovery"

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service), ScienceDirect (Online, ed. Modern chemical enhanced oil recovery: Theory and practice. Gulf Professional Pub., 2010.

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Lake, Larry W. Enhanced oil recovery. Prentice Hall, 1989.

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Ganiev, O. R., R. F. Ganiev, and L. E. Ukrainsky. Enhanced Oil Recovery. John Wiley & Sons, Inc., 2016. http://dx.doi.org/10.1002/9781119293859.

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Applied enhanced oil recovery. Prentice Hall, 1992.

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Carcoana, Aurel. Applied enhanced oil recovery. Prentice Hall, 1992.

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Pilc, Jennifer. Surfactants and enhanced oil recovery. Brunel University, 1988.

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Society of Petroleum Engineers of AIME, ed. Fundamentals of enhanced oil recovery. Society of Petroleum Engineers, 2014.

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Sagir, Muhammad, Muhammad Mushtaq, M. Suleman Tahir, Muhammad Bilal Tahir, and Abdul Ravoof Shaik. Surfactants for Enhanced Oil Recovery Applications. Springer International Publishing, 2020. http://dx.doi.org/10.1007/978-3-030-18785-9.

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Enhanced oil recovery handbook: A guide to heavy oil. Gulf Pub. Co., 2009.

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Steamflood reservoir management: Thermal enhanced oil recovery. PennWell Books, 1994.

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Book chapters on the topic "Chemical enhanced oil recovery"

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Sagir, Muhammad, Muhammad Mushtaq, M. Suleman Tahir, Muhammad Bilal Tahir, and Abdul Ravoof Shaik. "Challenges of Chemical EOR." In Surfactants for Enhanced Oil Recovery Applications. Springer International Publishing, 2020. http://dx.doi.org/10.1007/978-3-030-18785-9_7.

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Saha, Rahul, Pankaj Tiwari, and Ramgopal V. S. Uppaluri. "Nanofluid Flooding for Oil Recovery." In Chemical Nanofluids in Enhanced Oil Recovery. CRC Press, 2021. http://dx.doi.org/10.1201/9781003010937-5.

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Saha, Rahul, Pankaj Tiwari, and Ramgopal V. S. Uppaluri. "Problems and Challenges in Chemical EOR." In Chemical Nanofluids in Enhanced Oil Recovery. CRC Press, 2021. http://dx.doi.org/10.1201/9781003010937-6.

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Saha, Rahul, Pankaj Tiwari, and Ramgopal V. S. Uppaluri. "Introduction to Chemical and Nanofluids-Induced Oil Recovery." In Chemical Nanofluids in Enhanced Oil Recovery. CRC Press, 2021. http://dx.doi.org/10.1201/9781003010937-1.

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Saha, Rahul, Pankaj Tiwari, and Ramgopal V. S. Uppaluri. "Alkali and Surfactant Flooding." In Chemical Nanofluids in Enhanced Oil Recovery. CRC Press, 2021. http://dx.doi.org/10.1201/9781003010937-13.

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Saha, Rahul, Pankaj Tiwari, and Ramgopal V. S. Uppaluri. "Application of Nanotechnology in Unconventional Reservoirs." In Chemical Nanofluids in Enhanced Oil Recovery. CRC Press, 2021. http://dx.doi.org/10.1201/9781003010937-7.

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Saha, Rahul, Pankaj Tiwari, and Ramgopal V. S. Uppaluri. "Alkali Flooding – Mechanisms Investigation." In Chemical Nanofluids in Enhanced Oil Recovery. CRC Press, 2021. http://dx.doi.org/10.1201/9781003010937-2.

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Saha, Rahul, Pankaj Tiwari, and Ramgopal V. S. Uppaluri. "Surfactant Adsorption Characteristics on Reservoir Rock." In Chemical Nanofluids in Enhanced Oil Recovery. CRC Press, 2021. http://dx.doi.org/10.1201/9781003010937-4.

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Barenblatt, G. I., V. M. Entov, and V. M. Ryzhik. "Physico-Chemical Hydrodynamics of Enhanced Oil Recovery." In Theory of Fluid Flows Through Natural Rocks. Springer Netherlands, 1990. http://dx.doi.org/10.1007/978-94-015-7899-8_6.

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Liu, Keyu, and Xiaofang Wei. "Oil Recovery: Experiences and Economics of Microbially Enhanced Oil Recovery (MEOR)." In Consequences of Microbial Interactions with Hydrocarbons, Oils, and Lipids: Production of Fuels and Chemicals. Springer International Publishing, 2017. http://dx.doi.org/10.1007/978-3-319-31421-1_203-1.

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Conference papers on the topic "Chemical enhanced oil recovery"

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Shaharudin, Mohd Shahid M., Shlok Jalan, Rahim Masoudi, and Mohamad B. Othman. "Chemical EOR: Challenges for Full Field Simulation." In SPE Enhanced Oil Recovery Conference. Society of Petroleum Engineers, 2013. http://dx.doi.org/10.2118/165247-ms.

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Abbas, Sayeed, Aaron W. Sanders, and James C. Donovan. "Applicability of Hydroxyethylcellulose Polymers for Chemical EOR." In SPE Enhanced Oil Recovery Conference. Society of Petroleum Engineers, 2013. http://dx.doi.org/10.2118/165311-ms.

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Cheng, K. H. "Chemical Consumption During Alkaline Flooding: A Comparative Evaluation." In SPE Enhanced Oil Recovery Symposium. Society of Petroleum Engineers, 1986. http://dx.doi.org/10.2118/14944-ms.

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Henthorne, Lisa, Meghan Hartman, and Andrea Hayden. "Improving Chemical EOR Economics by Optimizing Water Quality." In SPE Enhanced Oil Recovery Conference. Society of Petroleum Engineers, 2011. http://dx.doi.org/10.2118/144397-ms.

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Koroteev, Dmitry Anatolyevich, Oleg Dinariev, Nikolay Evseev, et al. "Application of Digital Rock Technology for Chemical EOR Screening." In SPE Enhanced Oil Recovery Conference. Society of Petroleum Engineers, 2013. http://dx.doi.org/10.2118/165258-ms.

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Clifford, P. J. "Simulation of Small Chemical Slug Behavior in Heterogeneous Reservoirs." In SPE Enhanced Oil Recovery Symposium. Society of Petroleum Engineers, 1988. http://dx.doi.org/10.2118/17399-ms.

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Zhang, Fusheng, Jian Ouyang, Xinfang Feng, and Hong Lin. "A Chemical Agent Enhancing Recovery Of The Heavy Oil Reservoir." In SPE Enhanced Oil Recovery Conference. Society of Petroleum Engineers, 2011. http://dx.doi.org/10.2118/144788-ms.

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Qiang, Wang, Gao Ming, Liu Zhaoxia, Mohamad Abu Bakar, Yeap Yeow Chong, and Izwan B. Adnan. "Chemical EOR Evaluation for GNPOC and PDOC Fields in Sudan." In SPE Enhanced Oil Recovery Conference. Society of Petroleum Engineers, 2013. http://dx.doi.org/10.2118/165257-ms.

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Reksidler, R., R. A. M. Vieira, A. E. Orlando, B. R. S. Costa, and L. S. Pereira. "Offshore Chemical Enhanced Oil Recovery." In OTC Brasil. Offshore Technology Conference, 2015. http://dx.doi.org/10.4043/26123-ms.

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Nguyen, Duy Thai, Nick Sadeghi, and Christopher W. Houston. "Emulsion Characteristics and Novel Demulsifiers for Treating Chemical EOR Induced Emulsions." In SPE Enhanced Oil Recovery Conference. Society of Petroleum Engineers, 2011. http://dx.doi.org/10.2118/143987-ms.

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Reports on the topic "Chemical enhanced oil recovery"

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Bryant, R., K. Chase, K. Bertus, and A. Stepp. Effects of chemical additives on microbial enhanced oil recovery processes. Office of Scientific and Technical Information (OSTI), 1989. http://dx.doi.org/10.2172/5284479.

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Olsen, D. K. Use of amine oxide surfactants for chemical flooding EOR (enhanced oil recovery). Office of Scientific and Technical Information (OSTI), 1989. http://dx.doi.org/10.2172/5586604.

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Ameri, S., K. Aminian, J. A. Wasson, and D. L. Durham. Improved CO sub 2 enhanced oil recovery -- Mobility control by in-situ chemical precipitation. Office of Scientific and Technical Information (OSTI), 1991. http://dx.doi.org/10.2172/5614387.

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Kabadi, V. N. A study of the effects of enhanced oil recovery agents on the quality of Strategic Petroleum Reserves crude oil. [Physical and chemical interactions of Enhanced Oil Recovery reagents with hydrocarbons present in petroleum]. Office of Scientific and Technical Information (OSTI), 1992. http://dx.doi.org/10.2172/6643602.

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Shirish Patil, Abhijit Dandekar, and Mary Beth Leigh. Chemical and Microbial Characterization of North Slope Viscous Oils to Assess Viscosity Reduction and Enhanced Recovery. Office of Scientific and Technical Information (OSTI), 2008. http://dx.doi.org/10.2172/963366.

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Skone, Timothy J. Enhanced Oil Recovery Operations. Office of Scientific and Technical Information (OSTI), 2012. http://dx.doi.org/10.2172/1509375.

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Sharma, M. M., and G. Georgiou. Microbial enhanced oil recovery research. Office of Scientific and Technical Information (OSTI), 1990. http://dx.doi.org/10.2172/6878184.

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Skone, Timothy J. California Thermal Enhanced Oil Recovery. Office of Scientific and Technical Information (OSTI), 2009. http://dx.doi.org/10.2172/1509002.

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Sharma, M., and G. Georgiou. Microbial enhanced oil recovery research. Office of Scientific and Technical Information (OSTI), 1990. http://dx.doi.org/10.2172/6915859.

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Pautz, J. F., P. Sarathi, and R. Thomas. Review of EOR (enhanced oil recovery) project trends and thermal EOR (enhanced oil recovery) technology. Office of Scientific and Technical Information (OSTI), 1990. http://dx.doi.org/10.2172/7270418.

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