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Academic literature on the topic 'Fluid recovery'

Author: Grafiati

Published: 4 June 2021

Last updated: 17 June 2025

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Journal articles on the topic "Fluid recovery"

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Lê, Hồng Nguyên, Thị Tuyết Mai Đặng, Thị Bích Phương Đặng, and Thị Ánh Trinh Lưu. "Recovering heat of flue gas from heat recovery steam generator system at Nhon Trach 1 and Nhon Trach 2 gas power plants by organic Rankine cycle to produce power." Petrovietnam Journal 5 (July 4, 2022): 38–42. http://dx.doi.org/10.47800/pvj.2022.05-05.

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Flue gas from gas turbines at Nhon Trach 1 and Nhon Trach 2 gas power plant are in the temperature range of 100 - 113oC after heat has been recovered at the heat recovery steam generator. These heat flows are not recovered by conventional methods since they are not effective. Meanwhile, the organic Rankine cycle (ORC) uses organic fluids with low boiling point, that is why it can recover heat from low-temperature flue gas streams. Results of the ORC investigation reveal that with R245fa as a fluid, the Nhon Trach 1’s capacity will increase by 2.0 MW, and the Nhon Trach 2’s capacity will see an increase of 3.6 MW with R113 as a fluid.

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Hanshi, Zhang, Jiang Guancheng, Bi Hongxun, and Zhu Kuanliang. "Research on Protecting Formation Low-Damage Workover Fluid in Low Permeability Reservoir." International Journal of Nanoscience 18, no. 06 (2019): 1850049. http://dx.doi.org/10.1142/s0219581x18500497.

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During the workover treatment process, poorly compatible workover fluids infiltrating into reservoir could cause serious formation damage. To tackle the aformentioned issues, in this work, low-damage workover fluid was systematically studied. By investigating reservoir damage mechanisms, chemical property study, compatibility evaluation test and core flow test, we obtain three kinds of workover fluids suitable for different blocks in Nanpu oilfield. Attractively, JRYL workover fluid which contains antiswelling agents can effectively prevent water sensitivity, and the permeability recovery values of JRYL workover fluid to NP1-5 and PG2 core are 95.3% and 86.9%, respectively. JRYD workover fluid which contains antiswelling agents and anti-waterblocking agent can prevent both water sensitivity and water blocking damage, and the permeability recovery value of JRYD workover fluid to NP403X1 core is 89.4%. JRYJ workover fluid suitable for high pressure formation can prevent water sensitivity and water blocking damage, and the permeability recovery value of the JRYJ workover fluid to NP403X1 core is 95.1%. The actual field application in Nanpu oilfield indicates that these workover fluids can not only reduce the oil well recovery time after workover treatment, but also increase production recovery rate. These results display great potential to efficiently develop low permeability reservoirs.

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Bui, Khoa, and I. Yucel Akkutlu. "Hydrocarbons Recovery From Model-Kerogen Nanopores." SPE Journal 22, no. 03 (2016): 854–62. http://dx.doi.org/10.2118/185162-pa.

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Summary Existing strategies for oil and gas recovery are designed on the basis of macroscopic properties of the produced hydrocarbon fluids. However, recent studies on source rocks revealed that properties of fluids stored in nanopores of the organic constituent material kerogen deviate from the bulk behavior. Hence, the traditional equation-of-state (EOS) and fluid-properties correlations are no longer applicable. This, in turn, leads to added uncertainties in hydrocarbon-in-place and recovery calculations for the source rocks that are rich in kerogen. In this paper, we seek to address the question at a fundamental level from the thermodynamics standpoint by simulating isothermal expansion of a quinary hydrocarbon mixture in a model nanopore under typical subsurface conditions, and measuring the fluid composition and amount. Molecular Monte Carlo simulations are used to investigate the equilibrium relationship between the bulk fluid at the outside of the pore and the remaining mixture inside during the stages of pressure depletion. The fluid stored in nanopores shows a composition that varies significantly with the pore size. The smaller the pore is, the heavier becomes the mixture that is in equilibrium with the bulk fluid. During the depletion, the small hydrocarbon molecules escape readily from the pores. The composition of the remaining fluid inside the pore thus becomes progressively heavier and viscous. We show that nanopore confinement significantly limits the release of hydrocarbon molecules from the pores with sizes smaller than 10 nm. For each hydrocarbon component, a strong correlation exists between molar fractions of the component in the produced fluid with that which remained inside the pore. This correlation can serve in future studies as the basis for establishing alternative methods for reservoir-engineering calculations, such as the ultimate recovery.

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Fan, Pingtian, Yuetian Liu, Ziyu Lin, Haojing Guo, and Ping Li. "Experimental Study on the Efficiency of Fracturing Integrated with Flooding by Slickwater in Tight Sandstone Reservoirs." Processes 12, no. 11 (2024): 2529. http://dx.doi.org/10.3390/pr12112529.

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Tight reservoirs, with their nanoscale pore structures and limited permeability, present significant challenges for oil recovery. Composite fracturing fluids that combine both fracturing and oil recovery capabilities show great potential to address these challenges. This study investigates the performance of a slickwater-based fracturing fluid, combined with a high-efficiency biological oil displacement agent (HE-BIO), which offers both production enhancement and environmental compatibility. Key experiments included tests on single-phase flow, core damage assessments, interfacial tension measurements, and oil recovery evaluations. The results showed that (1) the slickwater fracturing fluid effectively penetrates the rock matrix, enhancing oil recovery while minimizing environmental impact; (2) it causes substantially less damage to the reservoir compared to traditional guar gum fracturing fluid, especially in cores with little higher initial permeability; and that (3) oil recovery improves as HE-BIO concentration increases from 0.5% to 2.5%, with 2.0% as the optimal concentration for maximizing recovery rates. These findings provide a foundation for optimizing fracturing oil displacement fluids in tight sandstone reservoirs, highlighting the potential of the integrated fracturing fluid to enhance sustainable oil recovery.

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Tian, Jie, Wende Yan, Zhilin Qi, Shiwen Huang, Yingzhong Yuan, and Mingda Dong. "Cyclic Supercritical Multi-Thermal Fluid Stimulation Process: A Novel Improved-Oil-Recovery Technique for Offshore Heavy Oil Reservoir." Energies 15, no. 23 (2022): 9189. http://dx.doi.org/10.3390/en15239189.

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Cyclic supercritical multi-thermal fluid stimulation (CSMTFS) is a novel technology that can efficiently recover heavy oil, while the heating effect, production and heat loss characteristics of CSMTFS have not been discussed. In this study, a physical simulation experiment of CSMTFS is conducted with a three-dimensional experimental system. The results of the study indicate that the whole process of CSMTFS can be divided into four stages, namely, the preheating stage, production increase stage, production stable stage and production decline stage, of which the production stable stage is the main oil production stage, and the production decline stage is the secondary oil production stage. In the first two stages of the CSMTFS process, there is no supercritical multi-thermal fluid chamber, and only a relatively small supercritical multi-thermal fluid chamber is formed in the last stage of the CSMTFS process. Out of the supercritical multi-thermal fluid chamber, supercritical water in the thermal fluids condensates to hot water and flows downward to heat the subjacent oil layer. At the same time, the non-condensate gas in the thermal fluids accumulates to the upper part of the oil layer and reduces heat loss. The analysis of heat loss shows that the heat loss rate gradually increases at first and then tends to be stable. Compared with conventional thermal fluid, the CSMTFS can more effectively reduce heat loss. The enthalpy value of supercritical multi-thermal fluid is significantly increased compared with that of multi-thermal fluid, which effectively solves the problem of insufficient heat carrying capacity of multi-thermal fluid. Overall, cyclic supercritical multi-thermal fluid stimulation can effectively solve the problems of conventional heavy oil thermal recovery technology in offshore heavy oil recovery; it is indeed a new improved-oil-recovery technique for offshore heavy oil. The findings of this study can help in better understanding the cyclic supercritical multi-thermal fluid stimulation process. This study is significant and helpful for application of CSMTFS technology in heavy oil recovery.

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Soundararajan, Srinath, and Mahalingam Selvaraj. "Investigations of protracted finned double pipe heat exchanger system for waste heat recovery from diesel engine exhaust." Thermal Science, no. 00 (2023): 143. http://dx.doi.org/10.2298/tsci230212143s.

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The need for energy and material savings, as well as environmental concerns, have helped to increase the demand for high-efficiency heat exchangers in the modern era. In practice, a heat exchanger or the direct ejection of the hot working fluid is used to recover the waste heat from a heat engine or thermal power plant into the environment. Waste heat of a heat engine or power plant is recovered to the environment via a heat exchanger or by direct ejection from the hot working fluid. In many situations, waste heat recovery removes or greatly reduces the necessity for additional fuel energy input to achieve this goal. The double pipe heat exchanger equipment is taken in this research, heat from engine exhaust recovers due to its superior qualities. The design characteristics of the heat pipe will be changed in order to increase overall efficiency by studying the concepts of various authors. Different design parameters for a double pipe heat exchange system as well as different working fluid flow rates are tested with the suggested device. Additionally, ANSYS performs computational fluid dynamics for the proposed heat exchanger system in order for the results to support the experimental findings.

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Kingsley Onyedikachi Omomo, Andrew Emuobosa Esiri, and Henry Chukwuemeka Olisakwe. "Advanced fluid recovery and recycling systems for offshore drilling: A conceptual approach." Engineering Science & Technology Journal 5, no. 10 (2024): 2884–96. http://dx.doi.org/10.51594/estj.v5i10.1626.

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Offshore drilling is a crucial component of global energy production, but it poses significant environmental challenges, particularly in managing drilling fluids. This paper presents a conceptual approach to advanced fluid recovery and recycling systems, focusing on the integration of innovative filtration and separation technologies to reduce waste and enhance sustainability. The review explores current challenges in traditional drilling fluid management, highlighting waste disposal's environmental and operational drawbacks. A detailed conceptual framework is provided, outlining the design principles of the proposed system and its potential to increase fluid recovery rates while minimizing environmental impact. The paper also examines the sustainability and economic benefits of fluid recycling, including cost savings and long-term contributions to more responsible drilling practices. Finally, the future outlook discusses advancements in recovery technologies, integration with broader sustainability initiatives, and the policy and regulatory considerations necessary for widespread adoption. This review underscores the importance of fluid recovery systems in driving sustainable offshore drilling and aligning the industry with global environmental goals. Keywords: Offshore Drilling, Fluid Recovery, Waste Management, Sustainability, Advanced Filtration, Environmental Impact.

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Elliott, M. L., and M. Prevatte. "Comparison of Damage to `Tifgreen' Bermudagrass by Petroleum and Vegetable Oil Hydraulic Fluids." HortTechnology 5, no. 1 (1995): 50–51. http://dx.doi.org/10.21273/horttech.5.1.50.

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Petroleum and vegetable oil hydraulic fluids were spread on `Tifgreen' bermudagrass at three volumes (125, 250, and 500 ml) and three temperatures (27, 49, and 94C) to simulate a turfgrass equipment leak. Initial damage, recovery, and effects for a 1-year period were compared among treatments. All hydraulic fluid treatments resulted in 100% leaf necrosis within 10 days of application. Turfgrass recovery was influenced primarily by the fluid volume. After recovery, only plots treated with petroleum hydraulic fluid were periodically chlorotic, resulting in lower turfgrass quality. Long-term negative effects of hydraulic leaks from golf course equipment may be reduced by using vegetable oil hydraulic fluid.

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Villero-Mandon, Jose, Peyman Pourafshary, and Masoud Riazi. "Oil/Brine Screening for Improved Fluid/Fluid Interactions during Low-Salinity Water Flooding." Colloids and Interfaces 8, no. 2 (2024): 23. http://dx.doi.org/10.3390/colloids8020023.

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Low-salinity water flooding/smart water flooding (LSWF/SWF) are used for enhanced oil recovery (EOR) because of the improved extraction efficiency. These methods are more environmentally friendly and in many scenarios more economical for oil recovery. They are proven to increase recovery factors (RFs) by between 6 and 20%, making LSWF/SWF technologies that should be further evaluated to replace conventional water flooding or other EOR methods. Fluid/fluid interaction improvements include interfacial tension (IFT) reduction, viscoelastic behavior (elastic properties modification), and microemulsion generation, which could complement the main mechanisms, such as wettability alteration. In this research, we evaluate the importance of fluid/fluid mechanisms during LSWF/SWF operations. Our study showed that a substantial decrease in IFT occurs when the oil asphaltene content is in the range of 0% to 3 wt.%. An IFT reduction was observed at low salinity (0–10,000 ppm) and a specific oil composition condition. Optimal IFT occurs at higher divalent ion concentrations when oil has low asphaltene content. For the oil with high asphaltene content, the sulfates concentration controls the IFT alteration. At high asphaltene concentrations, the formation of micro-dispersion is not effective to recover oil, and only a 5% recovery factor improvement was observed. The presence of asphaltene at the oil/low-salinity brine interface increases the energy required to disrupt it, inducing significant changes in the elastic moduli. In cases of low asphaltene content, the storage modulus demonstrates optimal performance at higher divalent concentrations. Conversely, at high asphaltene concentrations, the dominant factors to control the interface are paraffin content and temperature.

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Akramov, B. Sh ,., Sh Kh Umedov, and Zh F. Nuritdinov. "Influence of Fluid Recovery and Flushing Frequency on Oil Recovery." Oil and Gas Technologies 134, no. 3 (2021): 47–49. http://dx.doi.org/10.32935/1815-2600-221-134-3-47-49.

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The article deals with the influence of intensive fluid withdrawal on the oil production process and on the amount of anhydrous current and final oil recovery. The beneficial effect of high rates of fluid recovery on the rate of oil recovery ant the current oil recovery in the water period is the technological basis of the method of forced fluid recovery from the reservoir. It is shown that forced withdrawal allows to reduce the duration of the late stage and extend the period of profitable oil production.

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Dissertations / Theses on the topic "Fluid recovery"

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Sulak, Jodi Lopez. "Radon remediation using fluid-based recovery systems." Thesis, Georgia Institute of Technology, 2001. http://hdl.handle.net/1853/17061.

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Engström, Olle. "Optimization of fluid-based heat-recovery systems." Thesis, KTH, Hållbara byggnader, 2019. http://urn.kb.se/resolve?urn=urn:nbn:se:kth:diva-257876.

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This report aims to investigate how fluid-based heat-recovery systems for ventilation can be optimized. A high proportion of existing systems operate at lower efficiency than possible, and thus do not reach their full potential in terms of energy savings. The aim of this report has been to find out why, to identify which parameters affect the efficiency of such systems, and to develop a general methodology for optimization. As a method for execution, a literature study and field experiments were chosen. The results from the literature study showed that dimensioned efficiency, fluid flow in the circuit and degree of contamination of the system were important parameters that greatly affected performance. The field experiments largely confirmed this, but also showed that an implementation of the theoretically optimal fluid flow is not always beneficial to the performance, but higher flow should always be considered. The results also indicated a correlation between the fluid flow and the convective heat-transfer coefficient (U-value) in the heat exchangers. A methodology for optimization is presented in the discussion section. As a suggestion for further research, two possible directions are proposed - the potential of cleaning and the effect of the fluid flow.<br>Den här rapporten har syftat till att utreda hur vätskekopplade värmeåtervinningssystem för ventilation kan optimeras. En hög andel befintliga system fungerar med lägre verkningsgrad än vad som är möjligt, och uppnår därmed inte sin fulla potential vad gäller energibesparing. Målet med den här rapporten har varit att ta reda på varför, att identifiera vilka parametrar som påverkar dylika systems verkningsgrad, och att ta fram en generell metodik för optimering. Som metod för utförande gjordes först en litteraturstudie och senare fältexperiment som utgick ifrån vad litteraturstudien indikerade. Resultatet från litteraturstudien visade att dimensionerad verkningsgrad, vätskeflödet i kretsen och försmutsningsgrad av systemet var viktiga parametrar som påverkade prestandan i hög grad. Fältexperimenten bekräftade detta till stor del, men visade också att en implementering av det teoretiskt optimala vätskeflödet inte alltid är till gagn för prestandan, utan högre flöde borde alltid övervägas. Resultaten indikerade också en korrelation mellan vätskeflödet och det konvektiva övergångstalet (U-värdet) i värmeväxlarna. En metodik för optimering presenteras i diskussionsavsnittet. Som förslag på vidare forskning föreslås två möjliga inriktningar – rengöringens potential samt vätskeflödets inverkan.

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Kitsios, Vassili. "Recovery of fluid mechanical modes in unsteady separated flows." Poitiers, 2010. http://www.theses.fr/2010POIT2292.

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This study is concerned with the recovery of fluid mechanical modes that can be used to describe the physical properties of unsteady separated flows. The flow configuration of interest is a spanwise homogeneous NACA 0015 airfoil with leading edge laminar separation and turbulent recirculation. An in-depth understanding of the unsteady flow dynamics and fluid mechanical stability properties, can assist in the future development of more efficient separation control strategies. In order to provide a richer understanding of the physics, the flow fields are numerically generated, and characterised at various key Reynolds numbers leading up to the target turbulent case. Proper Orthogonal Decomposition modes are recovered to most efficiently represent the unsteady scales of motion, and linear stability modes are sought to identify how a perturbation will evolve in this unsteady environment. The generation of the Proper Orthogonal Decomposition modes can require very large amounts of data, and the current study presents a means of recovering these modes using parallel computation. To enable the stability analysis, a means of performing the calculation in steady two-dimensional flows of semi-complex geometry has been developed. The corrections required to perform the stability analysis in unsteady turbulent flows has also been identified by using a non-linear eddy viscosity model to close the triple decomposition stability equations. It is intended that the means of recovering these fluid mechanical modes can assist in the future development of reduced order models necessary for the control of unsteady separated flows<br>Cette étude s’intéresse à la détermination de modes pouvant être utilisés en mécanique des fluides pour décrire les propriétés physiques d'écoulements instationnaires décollés. La configuration d'écoulement qui nous intéresse est un profil d'aile NACA 0015 transversalement homogène caractérisé par un décollement laminaire au bord d'attaque et une zone de recirculation turbulente. Comprendre en profondeur la dynamique instationnaire de l'écoulement et ses propriétés de stabilité peut aider à améliorer l'efficacité de futures stratégies de contrôle de décollement. Afin de mieux appréhender la physique, l'écoulement est d’abord simulé puis caractérisé pour plusieurs valeurs du nombre de Reynolds allant jusqu’au régime turbulent. On retrouve alors que les modes obtenus par décomposition orthogonale aux valeurs propres (Proper Orthogonal Decomposition) représentent de manière efficace les échelles instationnaires du mouvement. Par ailleurs, les modes de stabilité linéaire sont recherchés afin d'identifier comment une perturbation évolue dans un environnement instationnaire. La détermination des modes de Proper Orthogonal Decomposition pouvant nécessiter une grande quantité de données, cette étude présente un moyen de les évaluer par calcul parallèle. Pour permettre l'analyse de stabilité, il a fallu développer des programmes permettant de réaliser les calculs pour un écoulement stationnaire bidimensionnel en géométrie semi-complexe. Les corrections nécessaires pour effectuer l'analyse de stabilité dans des écoulements turbulents instationnaires ont aussi été identifiés en utilisant un modèle de viscosité tourbillonnaire non linéaire pour fermer les équations de stabilité en décomposition triple. La détermination de ces modes en mécanique des fluides doit aider le développement futur de modèles réduits nécessaires au contrôle d'écoulement instationnaire décollé

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CANTIANI, ANTONIO. "Improving the efficiency of fluid machinery through waste-heat recovery." Doctoral thesis, Università degli studi della Basilicata, 2022. http://hdl.handle.net/11563/154805.

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Panesar, Angad Singh. "Waste heat recovery using fluid bottoming cycles for heavy duty diesel engines." Thesis, University of Brighton, 2015. https://research.brighton.ac.uk/en/studentTheses/2e7faf1c-93fc-47b7-90f7-a6704ea95230.

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A typical long-haul heavy duty Diesel engine currently rejects up to 50% of the total fuel energy in the form of heat. Due to increasing CO2 emissions and fuel costs, there is a growing interest in techniques that can even partially utilise this wasted resource to improve the overall system efficiency. Fluid Bottoming Cycles (FBC) including Rankine and organic Rankine cycles offer one means towards converting waste heat into usable power. This thesis investigates the potential of FBCs to improve the net power of two computationally modelled (Ricardo WAVE V8.1) 10 litre engine platforms operating at Euro 6 emission levels.

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Agena, Bashir M. "Hot fluid injection into heavy oil reservoirs intercepted by a stationary vertical fracture /." Access abstract and link to full text, 1986. http://0-wwwlib.umi.com.library.utulsa.edu/dissertations/fullcit/8703435.

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Folefac, A. N. "Reservoir simulation of heavy oil recovery by hot fluid injection in horizontal wells." Thesis, Imperial College London, 1988. http://hdl.handle.net/10044/1/11372.

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Bennour, Ziad. "Effect of Hydraulic Fracturing Fluid Viscosity on Stimulated Reservoir Volume for Shale Gas Recovery." 京都大学 (Kyoto University), 2017. http://hdl.handle.net/2433/225563.

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Bezuidenhout, Johan Jacobus. "Computational fluid dynamic modelling of an electric smelting furnace in the platinum recovery process." Thesis, Stellenbosch : Stellenbosch University, 2008. http://hdl.handle.net/10019.1/2022.

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Thesis (MScEng (Process Engineering))--Stellenbosch University, 2008.<br>The electric smelting furnace is found at the heart of the platinum recovery process where the power input from the electrodes produces a complex interplay between heat transfer and fluid flow. A fundamental knowledge of the dynamic system hosted by the electric furnace is valuable for maintaining stable and optimum operation. However, describing the character of the system hosted by the electric furnace poses great difficulty due to its aggressive environment. A full-scale threedimensional Computational Fluid Dynamics (CFD) model was therefore developed for the circular, three-electrode Lonmin smelting furnace. The model was solved as time dependent to incorporate the effect of the three-phase AC current, which was supplied by means of volume sources representing the electrodes. The slag and matte layers were both modelled as fluid continuums in contact with each other through a dynamic interface made possible by the Volume of Fluid (VOF) multi-phase model. CO-gas bubbles forming at electrode surfaces and interacting with the surrounding fluid slag were modelled through the Discrete Phase Model (DPM). To account for the effect of concentrate melting, distinctive smelting zones were identified within the concentrate as assigned a portion of the melting heat based on the assumption of a radially decreasing smelting rate from the centre of the furnace. The tapping of slag and matte was neglected in the current modelling approach but compensation was made for the heating-up of descending material by means of an energy sink based on enthalpy differences. Model cases with and without CO-gas bubbles were investigated as well as the incorporation of a third phase between the slag and matte for representing the ‘mushy’ chromite/highly viscous slag commonly found in this region. These models were allowed to iterate until steady state conditions has been achieved, which for most of the cases involved several weeks of simulation time. The results that were obtained provided good insight into the electrical, heat and flow behaviour present within the molten bath. The current density profiles showed a large portion of the current to flow via the matte layer between the electrodes. Distributions for the electric potential and Joule heat within the melt was also developed and showed the highest power to be generated within the immediate vicinity of the electrodes and 98% of the resistive heat to be generated within the slag. Heat was found to be uniformly distributed due the slag layer being well mixed. The CO-gas bubbles was shown to be an important contributor to flow within the slag, resulting in a order of magnitude difference in average flow magnitude compared to the case where only natural buoyancy is at play. The highest flow activity was observed halfway between electrodes where the flow streams from the electrodes meet. Consequently, the highest temperatures are also observed in these regions. The temperature distribution within the matte and concentrate layers can be characterized as stratified. Low flow regions were identified within the matte and bottom slag layer which is where chromite and magnitite deposits are prone to accumulate. The model results were partially validated through good agreement to published results where actual measurements were done while also falling within the typical operating range for the actual furnace. The modelling of the electric furnace has been valuably furthered, however for complete confidence in the model results, further validation is strongly recommended.

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Morton, Alison. "Higher order Godunov IMPES compositional modelling of oil reservoirs." Thesis, University of Reading, 1996. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.320187.

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Books on the topic "Fluid recovery"

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Dr, King P. R., Institute of Mathematics and Its Applications., and Society of Petroleum Engineers (U.K.), eds. The Mathematics of oil recovery. Clarendon Press, 1992.

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Munka, Margit. 4D numerical modeling of petroleum reservoir recovery. Akadémiai Kiadó, 2001.

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Paul, Pare, ed. Recovery analysis: New methods and a computer program in well hydraulics. Water Resources Publications, 1996.

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Mao, Tie. Simulation of the fluid flow around the primary air ports of a kraft recovery boiler. National Library of Canada, 1993.

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Demir, Ilham. Formation water chemistry and modeling of fluid-rock interaction for improved oil recovery in Aux Vases and Cypress Formations, Illinois basin. Illinois State Geological Survey, 1995.

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R, Walsh Kevin, and NASA Dryden Flight Research Center., eds. Inlet distortion for an F/A-18A aircraft during steady aerodynamic conditions up to 60 ̊angle of attack: Contract NAS 3-26617. National Aeronautics and Space Administration, Dryden Flight Research Center, 1997.

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Silva, Matthew. Fluid injection for salt water disposal and enhanced oil recovery as a potential problem for the WIPP: Proceedings of a June 1995 workshop and analysis. Environmental Evaluation Group, 1996.

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Erkey, Can. Supercritical fluids and organometallic compounds: From recovery of trace metals to synthesis of nanostructured materials. Elsevier, 2011.

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Manual: Alternative methods for fluid delivery and recovery. The Center, 1994.

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Solution mining: Leaching and fluid recovery of materials. 2nd ed. Gordon and Breach Science Publishers, 1998.

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Book chapters on the topic "Fluid recovery"

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Stessel, Richard Ian. "Fluid Separation." In Recycling and Resource Recovery Engineering. Springer Berlin Heidelberg, 1996. http://dx.doi.org/10.1007/978-3-642-80219-5_6.

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Mandal, Ajay, and Keka Ojha. "Fundamentals of Immiscible Fluid Displacement Processes." In Enhanced Oil Recovery. CRC Press, 2023. http://dx.doi.org/10.1201/9781003098850-2.

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Van Ginneken, Luc, and Herman Weyten. "Supercritical Fluid Chromathography (SFC)." In Carbon Dioxide Recovery and Utilization. Springer Netherlands, 2003. http://dx.doi.org/10.1007/978-94-017-0245-4_4.

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Tewari, Raj Deo, Abhijit Y. Dandekar, and Jaime Moreno Ortiz. "Fluid Characterization and Recovery Mechanism." In Petroleum Fluid Phase Behavior. CRC Press, 2018. http://dx.doi.org/10.1201/9781315228808-2.

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Zhang, Yangjun, Weilin Zhuge, Shuyong Zhang, and Jianzhong Xu. "Through Flow Models for Engine Turbocharging and Exhaust Heat Recovery." In Fluid Machinery and Fluid Mechanics. Springer Berlin Heidelberg, 2009. http://dx.doi.org/10.1007/978-3-540-89749-1_32.

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Rollins, Katie E., and Dileep N. Lobo. "Perioperative Intravenous Fluid Therapy in ERAS Pathways." In Enhanced Recovery After Surgery. Springer International Publishing, 2020. http://dx.doi.org/10.1007/978-3-030-33443-7_18.

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Hainaut, J. L., J. Henrard, J. M. Hick, D. Roland, and V. Englebert. "Database design recovery." In Notes on Numerical Fluid Mechanics and Multidisciplinary Design. Springer International Publishing, 1996. http://dx.doi.org/10.1007/3-540-61292-0_16.

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Cumpstey, Andrew F., Michael P. W. Grocott, and Michael (Monty) G. Mythen. "Fluid Management and Its Role in Enhanced Recovery." In Perioperative Fluid Management. Springer International Publishing, 2020. http://dx.doi.org/10.1007/978-3-030-48374-6_15.

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Cumpstey, Andrew F., Michael P. W. Grocott, and Michael G. Mythen. "Fluid Management and Its Role in Enhanced Recovery." In Perioperative Fluid Management. Springer International Publishing, 2016. http://dx.doi.org/10.1007/978-3-319-39141-0_13.

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Varadhan, Krishna K., and Dileep N. Lobo. "Perioperative Fluid Management in Enhanced Recovery." In Manual of Fast Track Recovery for Colorectal Surgery. Springer London, 2011. http://dx.doi.org/10.1007/978-0-85729-953-6_5.

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Conference papers on the topic "Fluid recovery"

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Zitha, P. L. J., and F. Wessel. "Fluid Flow Control Using Magnetorheological Fluids." In SPE/DOE Improved Oil Recovery Symposium. Society of Petroleum Engineers, 2002. http://dx.doi.org/10.2118/75144-ms.

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Mukherjee, Sanchay, Russell T. Johns, Sajjad Foroughi, and Martin J. Blunt. "Fluid – Fluid Interfacial Area and Its Impact on Relative Permeability - A Pore Network Modeling Study." In SPE Improved Oil Recovery Conference. SPE, 2022. http://dx.doi.org/10.2118/209445-ms.

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Abstract Relative permeability (kr) is commonly modeled as an empirical function of phase saturation. Although current empirical models can provide a good match of one or two measured relative permeabilities using saturation alone, they are unable to predict relative permeabilities well when there is hysteresis or when physical properties such as wettability change. Further, current models often result in relative permeability discontinuities that can cause convergence and accuracy problems in simulation. To overcome these problems, recent research has modeled relative permeability as a state function of both saturation (S) and phase connectivity (X). Pore network modeling (PNM) data, however, shows small differences in relative permeability for the same S-X value when approached from a different flow direction. This paper examines the impact of one additional Minkowski parameter (Mecke and Arns, 2005), the fluid-fluid interfacial area, on relative permeability to identify if that satisfactorily explains this discrepancy. We calculate the total fluid-fluid interfacial areas (IA) during two-phase (oil/water) flow in porous media using pore network modeling. The area is calculated from PNM simulations using the areas associated with corners and throats in pore elements of different shapes. The pore network is modeled after a Bentheimer sandstone, using square, triangular, and circular pore shapes. Simulations were conducted for numerous primary drainage and imbibition cycles at a constant contact angle of 0° for the wetting phase. Simultaneous measurements of capillary pressure, relative permeability, saturation, and phase connectivity are made for each displacement. Fluid-fluid interfacial area is calculated from the PNM capillary pressure, the fluid location in the pore elements, and the pore element dimensional data. The results show that differences in the relative permeability at the same (S,X) point is explained well by differences in the fluid-fluid interfacial area (IA). That is, for a larger change in IA at these intersection points, the permeability difference is greater. That difference in relative permeability approaches zero as the difference in IA approaches zero. This confirms that relative permeability can be modeled better as a unique function of S, X, and IA. The results also show that an increase in IA restricts flow decreasing the nonwetting (oil) phase permeability. This decrease is caused by an increase in the throat area fraction compared to the corner area as the total area IA increases. The wetting phase relative permeability, however, shows the inverse trend, in that its relative permeability is greater when IA becomes larger owing to a greater fraction of the total area associated with the corners. The area IA, however, impacts the nonwetting phase relative permeability more than the wetting phase relative permeability. Corner flow improves the wetting phase relative permeability because the wetting phase is continuous there. Finally, a sensitivity analysis shows that relative permeability a is more sensitive to change in S than they are for IA for the case studied implying that if only two parameters are used to model relative permeability it is better to choose S and X.

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Abdeslam-Hassen, Meniai, Louaer Mehdi, Zermane Ahmed, and Outili Nawel. "Supercritical Fluid Enhanced Oil Recovery." In 2022 13th International Renewable Energy Congress (IREC). IEEE, 2022. http://dx.doi.org/10.1109/irec56325.2022.10002123.

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Yonebayashi, Hideharu, Takeshi Hiraiwa, Masaaki Tange, et al. "Functional Components in Low Salinity Waterflood Forming Micro-Dispersion Phase via Fluid-Fluid Interaction in Carbonate Reservoirs." In SPE Improved Oil Recovery Conference. SPE, 2024. http://dx.doi.org/10.2118/218172-ms.

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Abstract Low salinity water (LSW) enhanced oil recovery (EOR) has gained more attention in carbonate reservoirs with a variety of mechanism hypotheses. Recent research focused on fluid-fluid interaction (FFI) during LSW injection, especially forming water micro-dispersion (MD) as a potential drivers of oil recovery improving mechanism in LSW EOR. This paper elucidates functional components in positive crude oil which showed high MD ration in FFI test and additional oil recovery in LSW core flood experiments. Four stock tank oil (STO) samples were collected from multiple sub-layers (L1, L2, L3, and U). Synthetic brine was prepared as LSW to mimic the sea water (SW) diluted to 1%. The FFI tests measured MD ratios, which represent water content increment caused by the oil-water interfacial chemical reactions, to screen positive oil for low-salinity effect. During the FFI, 3 types of sub-samples were collected as original oil, MD phase, and post-FFI oil. Each sample was fractionated to 7 compositions: Saturates, 1-/2-/3+-ring Aromatics, Polar Resins, Poly Aromatic Resins, and Asphaltenes. Subsequently, all composition were investigated by Fourier-transform ion cyclotron resonance mass spectrometer (FT-ICR MS) to find out functional components. Based on MD ratios, three of four STOs were selected as the candidates for FT-ICR MS analysis. STO-L2 and STO-L3 were categorized as positive oil and partially positive oil, respectively. STO-U was picked out as negative oil because of the lowest MD ratio. Functional components, which are generally considered as surface-active components, are assumed to be predominantly contained in positive oil and MD sub-samples compared with negative oil and post-FFI oil, respectively. Therefore, two series of differential analysis were performed for: (a) a group of original oils (STO-L2 vs. STO-U); and (b) a group of positive oils (STO-L2, MD fluid, and post-FFI oil) using the double-bond-equivalent (DBE) vs. carbon number (CN) plot. The differential analysis of positive/negative oils revealed that asphaltenes in positive oil consisted of higher DBE composition. Noticeable differences were observed for asphaltenes and polar resins in a series of positive oil during FFI test. Higher DBE asphaltenes moved from the original oil to MD phase, while majority of polar resins remained in the post-FFI oil. In general, asphaltenes are stabilized with being surrounded by resins. However, analysis result suggests that surrounding polar resins were detached from asphaltene by the interaction between LSW and asphaltenes’ surface-active components. This may result in decreasing polar resins in MD phase. The study demonstrates the change in chemical composition of crude oil depending on positive oil characteristic or contact by LSW. These compositional differences provide us with important clues about the FFI mechanism of LSW through which further oil recovery may be achieved. Deployment of FT-ICR MS analysis elucidated functional components such as higher DBE asphaltenes which might promote the spontaneous formation of water-in-oil micro-dispersion at the oil/LSW interface.

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Ma, Ming, and Hamid Emami-Meybodi. "Inhomogeneous Fluid Transport Modeling of Gas Injection in Shale Reservoirs Considering Fluid-Solid Interaction and Pore Size Distribution." In SPE Improved Oil Recovery Conference. SPE, 2024. http://dx.doi.org/10.2118/218267-ms.

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Abstract Gas injection presents unique enhanced oil recovery (EOR) mechanisms in shale reservoirs compared to conventional reservoirs due to the complex nature of fluid transport and fluid-solid interaction in nanopores. We propose a multiphase multicomponent transport model for primary production and gas injection in shale reservoirs considering dual scale porous medium and fluid-solid interactions in nanopores. The shale matrix is separated into macropore and nanopore based on pore size distribution. The density functional theory is employed, accounting for fluid-solid interactions, to compute the inhomogeneous fluid density distribution and phase behavior within multiscale matrix. The calculated fluid thermodynamic properties and transmissibility values are then integrated into the multiphase multicomponent transport model grounded in the Maxwell-Stefan theory to simulate primary production and gas injection processes. Our research underscores the precision of density functional theory in capturing intricate fluid inhomogeneities within nanopores, which is overlooked by the cubic equation of state. The fluid system within varying pores can be classified into confined fluid and bulk fluid, separated by a pore width threshold of 30 nm. Distinct fluid compositions are observed in macropores and nanopores, with heavy components exhibiting a preference for distribution in nanopores due to stronger fluid-solid interactions compared to light components. During primary production period, the robust fluid-solid interactions in nanopores impede the mobility of heavy components, leading to their confinement. Consequently, heavy components within nanopores are difficult to extract during primary production processes. During the CO2 injection period, the injected CO2 induces a significant alteration in fluid composition within both macropores and nanopores, promoting fluid redistribution. The competitive fluid-solid interaction of CO2 results in efficient adsorption on pore walls, displacing propane from nanopores.

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Tetteh, Joel T., Saman A. Aryana, and Reza Barati Ghahfaorkhi. "An Investigation into Fluid-Fluid Interaction Phenomenon During Low Salinity Waterflooding using a Reservoir-on-a-Chip Microfluidics Model." In SPE Improved Oil Recovery Conference. Society of Petroleum Engineers, 2020. http://dx.doi.org/10.2118/200380-ms.

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Dzulkarnain, Iskandar, Mariyamni Bt Awang, and Ahmad Muzakkir Mohamad. "Uncertainty in MMP Prediction from EOS Fluid Characterization." In SPE Enhanced Oil Recovery Conference. Society of Petroleum Engineers, 2011. http://dx.doi.org/10.2118/144405-ms.

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Pinnawala, Gayani W., Guo-qing Tang, Mohamad Salman, et al. "Fracture-Fluid Chemistry Optimization to Improve Hydrocarbon Recovery for Shale and Tight Assets." In SPE Improved Oil Recovery Conference. SPE, 2024. http://dx.doi.org/10.2118/218151-ms.

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Abstract The active development of unconventional shale and tight reservoirs worldwide has helped unlock vast quantities of hydrocarbons in recent years. Hydraulic fracturing operations in horizontal wells is the most common method applied to unconventional reservoirs to unlock hydrocarbon resources by undergoing multiple fracturing stages. A common mixture of friction reducer, scale inhibitor, and other situational additives along with a carrier fluid, (brackish or recycled produced water) make up the completion or frac fluid. Often, the frac fluid is a colloidal suspension, as noted by the larger particle size distribution within the fluid. When exposed to reservoir conditions (elevated temperature, high formation brine salinity, high divalent ion concentration), frac fluids can destabilize due to the presence of polyacrylamide acting as a flocculant. Such behavior causes phase-separation and precipitation resulting in formation damage. Another scenario is the rapid production rate decline seen in hydraulically fractured horizontal wells. Typically, their production rates rapidly decline until stabilizing at a low terminal rate. Overcoming these trends to improve recovery is a major challenge. Fracture Fluid Chemistry Optimization (FFCO) technology development focuses on increasing recovery by designing and optimizing fracturing fluids for stimulation of shale formations. This stimulation fluid maintains clean fractures and penetrates deeper into the fracture network, mobilizing more hydrocarbons by altering rock wettability and lowering interfacial tension (IFT). The surfactants also alter the relative permeability to a more favorable state in the propped fractures. This work describes a workflow to optimize treatment fluids for injection into shale and tight rock reservoirs. The workflow incorporates rock and fluid property measurements and compatibility assessments between rock, reservoir fluids and frac fluids at the laboratory scale.

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Geilikman, M. B., M. B. Dusseault, and F. A. Dullien. "Fluid Production Enhancement by Exploiting Sand Production." In SPE/DOE Improved Oil Recovery Symposium. Society of Petroleum Engineers, 1994. http://dx.doi.org/10.2118/27797-ms.

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Bizanti, M. S., and E. F. Blick. "Fluid Dynamics of Wellbore Bottomhole Cleaning." In Permian Basin Oil and Gas Recovery Conference. Society of Petroleum Engineers, 1986. http://dx.doi.org/10.2118/15010-ms.

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Reports on the topic "Fluid recovery"

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Mayes, Richard T., Phillip W. Halstenberg, Bruce A. Moyer, Athanasios Karamalidis, and Clint Noack. Selective Recovery of Critical Materials from Geothermal Fluid. Office of Scientific and Technical Information (OSTI), 2018. http://dx.doi.org/10.2172/1432158.

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Seright, R. Improved techniques for fluid diversion in oil recovery. Final report. Office of Scientific and Technical Information (OSTI), 1996. http://dx.doi.org/10.2172/188919.

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Abadie, Marc O., Elizabeth U. Finlayson, and Ashok J. Gadgil. Infiltration heat recovery in building walls: Computational fluid dynamics investigations results. Office of Scientific and Technical Information (OSTI), 2002. http://dx.doi.org/10.2172/803859.

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Seright, R. S. Improved techniques for fluid diversion in oil recovery. First annual report. Office of Scientific and Technical Information (OSTI), 1993. http://dx.doi.org/10.2172/10120646.

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Seright, F. S., and F. D. Martin. Fluid diversion and sweep improvement with chemical gels in oil recovery processes. Office of Scientific and Technical Information (OSTI), 1991. http://dx.doi.org/10.2172/5990654.

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Seright, R. S., and F. D. Martin. Fluid Diversion and Sweep Improvement with Chemical Gels in Oil Recovery Processes. Office of Scientific and Technical Information (OSTI), 1991. http://dx.doi.org/10.2172/6283069.

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Panicker, Nithin, Marco Delchini, Thomas Sambor, and Adrian Sabau. COMPUTATIONAL FLUID DYNAMICS SIMULATIONS TO PREDICT OXIDATION IN HEAT RECOVERY STEAM GENERATOR TUBES. Office of Scientific and Technical Information (OSTI), 2022. http://dx.doi.org/10.2172/1888933.

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Seright, R. S., and F. D. Martin. Fluid diversion and sweep improvement with chemical gels in oil recovery processes. Final report. Office of Scientific and Technical Information (OSTI), 1992. http://dx.doi.org/10.2172/10170924.

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Watson, R. An experimental and theoretical study to relate uncommon rock/fluid properties to oil recovery. Final report. Office of Scientific and Technical Information (OSTI), 1995. http://dx.doi.org/10.2172/90388.

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Fairbank, Brian D. Recovery Act. Sub-Soil Gas and Fluid Inclusion Exploration and Slim Well Drilling, Pumpernickel Valley, Nevada. Office of Scientific and Technical Information (OSTI), 2015. http://dx.doi.org/10.2172/1176929.

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