Relevant bibliographies by topics / Dual concentric injector

Academic literature on the topic 'Dual concentric injector'

Author: Grafiati
Published: 10 December 2022
Last updated: 29 January 2023

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Journal articles on the topic "Dual concentric injector"

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Vásquez, R. A., and F. S. Costa. "SPRAY CONE ANGLES GENERATED BY A DUAL CENTRIFUGAL INJECTOR." Revista de Engenharia Térmica 13, no. 1 (June 30, 2014): 36. http://dx.doi.org/10.5380/reterm.v13i1.62067.

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A dual pressure swirl injector is characterized by two independent concentric chambers which can provide independent rotational levels to a single liquid or two different liquids. This paper compares theoretical, semi-empirical and experimental results concerning the spray cone angles formed by injection of water, ethanol and biodiesel through a dual pressure swirl injector. Data are obtained for injection of the same liquid through the primary and secondary chambers and for injection of ethanol in the primary chamber and biodiesel through the secondary chamber of the injector. Experimental data are obtained using photographic techniques and are analyzed by an image processing software developed in Matlab language.
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Douglas, David N., Amy J. Managh, Helen J. Reid, and Barry L. Sharp. "High-Speed, Integrated Ablation Cell and Dual Concentric Injector Plasma Torch for Laser Ablation-Inductively Coupled Plasma Mass Spectrometry." Analytical Chemistry 87, no. 22 (October 28, 2015): 11285–94. http://dx.doi.org/10.1021/acs.analchem.5b02466.

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Liu, Hong Qin, Zai Hong Shi, Jing Zhu, and Zhen Ma. "Optimized Design and Research on Technology Parameters of Concentric Dual-Tube Steam Injection Horizontal Well." Applied Mechanics and Materials 675-677 (October 2014): 1505–11. http://dx.doi.org/10.4028/www.scientific.net/amm.675-677.1505.

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The screen pipe completion is the predominated method for heavy oil horizontal well in Liaohe Oilfield, accounting for 83.4% of the total completions. General steam injection has been used for the horizontal wells, resulting in a better exploitation percentage in heel part but a poorer exploitation percentage beyond 1/3 of the distance from the tiptoe to heel in horizontal well. As the concentric dual-tube steam injection technique for horizontal well has just been developed in Liaohe Oilfield, the related supporting technique is not enough. In this paper, researchers consider achieving horizontal wells concentric dual-tube steam injection optimized design as main goal so that the physical model will be established, and also the calculation methods for pressure, the calculation models for quality, heat loss and tapered string parameters along the wellbore will be provided during the concentric dual-tube steam injection for horizontal wells.
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Sun, Fengrui, Yuedong Yao, Guozhen Li, and Xiangfang Li. "Numerical Simulation of Supercritical-Water Flow in Concentric-Dual-Tubing Wells." SPE Journal 23, no. 06 (August 25, 2018): 2188–201. http://dx.doi.org/10.2118/191363-pa.

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Summary Much work has been performed on the modeling of saturated/superheated-steam flow in wellbores. At present, the study on supercritical-water (SCW) flow in wellbores, especially concentric-dual-tubing wells (CDTWs), is very limited. In this paper, work was performed on modeling of SCW flow in CDTWs. First, a comprehensive mathematical model comprising a pipe-flow model, supercritical-fluid model, and heat-transfer model is established. In the model, the heat exchange between the integral joint tubing (IJT) and annuli is taken into consideration. Numerical solutions of SCW flow in CDTWs were obtained with a straightforward numerical method. Then, sensitivity analysis was conducted. The following results were found: SCW in annuli (with a higher temperature) releases thermal energy to SCW in the IJT, which causes increase of temperature in IJT. As a result, SCW density in the IJT has a decrease. The density gradient near the wellhead increases with increasing of injection rate. When the injection temperature in the IJT is larger than that in annuli, SCW density increases with well depth near the wellhead.
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Zhang, Yi, Jiexiang Wang, Peng Jia, Xiao Liu, Xuxu Zhang, Chang Liu, and Xiangwei Bai. "Viscosity Loss and Hydraulic Pressure Drop on Multilayer Separate Polymer Injection in Concentric Dual-Tubing." Energies 13, no. 7 (April 2, 2020): 1637. http://dx.doi.org/10.3390/en13071637.

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Multilayer separate polymer injection in concentric dual-tubing is a special method for enhancing oil recovery in later development stage of the multilayer formation. During the injection process, heat exchange occurs among the inner tubing, tubing annulus and formation, making the thermal transfer process more complicated than traditional one. This work focuses on the polymer flowing characteristics during the multilayer separate polymer flooding injection process in the wellbore. A temperature–viscosity numerical model is derived to investigate the influencing factors on polymer dual-tubing injection process. Then, an estimate-correct method is introduced to derive the numerical solutions. Several influences have been discussed, including the axial temperature distribution, viscosity distribution, pressure drop, and flow pattern of polymer. Results show that under low injecting rates, below 5 m3/d, formation temperature will greatly decrease the polymer viscosity. When the injecting rates above 20 m3/d, the polymer just decreases 1–3 mPa·s at the bottom of well, which is really small. Additionally, the temperature distribution, the coefficient of friction under different injecting rates have been discussed. Generally, this method provides a new way to analyze thermal conductivity during the polymer injection process which is meaningful for polymer flooding in the oilfield application.
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Jiaming Zhang, Xiaodong Wu, Jingyao Wang, Shuai Xing, and Zhuang Zhang. "A New Wellbore Flow Model of CO2 Separate Injection with Concentric Dual Tubes." International Journal of Advancements in Computing Technology 4, no. 23 (December 31, 2012): 258–65. http://dx.doi.org/10.4156/ijact.vol4.issue23.31.

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Hunt, S. W., C. S. Brauer, M. B. Craddock, K. J. Higgins, A. M. Nienow, and K. R. Leopold. "Microwave observation of H3N–SO3⋯H2O using a concentric, dual-injection nozzle source." Chemical Physics 305, no. 1-3 (October 2004): 155–64. http://dx.doi.org/10.1016/j.chemphys.2004.06.040.

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Ma, Chuan, Xiaoyan Liu, Haiqian Zhao, and Guangfu Cui. "Influence of Vertical Downward Annulus Eccentricity on Steam-Water Two-Phase Flow Pressure Drop." Mathematical Problems in Engineering 2022 (April 7, 2022): 1–12. http://dx.doi.org/10.1155/2022/7682520.

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Concentric dual-tubing steam injection technique is one of the main methods to improve heavy oil recovery efficiency. From field data, it was discovered that hot fluid at high temperature and pressure caused steam injection casing to have elongation strain and “necking” eccentric buckling, and the eccentricity change affected the accurate prediction of steam-water two-phase flow pressure drop in the steam injection casing. This paper established a coupling model for the steam-water two-phase flow pressure drop in vertical downward eccentric annulus and the wellbore heat transfer and developed a mathematical model calculation program, to validate the accuracy of calculating the liquid holdup and pressure gradient of fully eccentric annulus. This revealed the influential law of eccentricity on the annulus steam-water two-phase pressure, dryness, and enthalpy value. The results indicated that when the eccentricity e increased from 0 to 1, the saturation pressure of steam at annulus wellbore bottom increased by 0.265 MPa, and the dryness and enthalpy value decreased by 8.54 × 10−3 and 11.22 kJ kg−1, respectively. Compared to the concentric layout, the eccentrically arranged steam injection inner tube cannot promote the wet steam dryness at annulus wellbore bottom.
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Eufrásio-da-Silva, Tatiane, Eduardo Ruiz-Hernandez, Joanne O’Dwyer, Dolores Picazo-Frutos, Garry P. Duffy, and Bruce P. Murphy. "Enhancing medial layer recellularization of tissue-engineered blood vessels using radial microchannels." Regenerative Medicine 14, no. 11 (November 2019): 1013–28. http://dx.doi.org/10.2217/rme-2019-0011.

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Aim: Cell repopulation of tissue-engineered vascular grafts (TEVGs) from decellularized arterial scaffolds is limited by dense concentric tunica media layers which impede cells migrating radially between the layers. We aimed to develop and validate a new microneedle device to modify decellularized carotid arteries with radial microchannels to enhance medial layer repopulation. Material & methods: Modified decellularized porcine arteries were seeded with rat mesenchymal stem cells using either standard longitudinal injection, or a dual vacuum-perfusion bioreactor. Mechanical tests were used to assess the arterial integrity following modification. Results & conclusion: The method herein achieved radial recellularization of arteries in vitro without significant loss of mechanical integrity, Thus, we report a novel method for successful radial repopulation of decellularized carotid artery-based tissue-engineered vascular grafts.
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Gu, Hao, Linsong Cheng, Shijun Huang, Baojian Du, and Changhao Hu. "Prediction of thermophysical properties of saturated steam and wellbore heat losses in concentric dual-tubing steam injection wells." Energy 75 (October 2014): 419–29. http://dx.doi.org/10.1016/j.energy.2014.07.091.

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Conference papers on the topic "Dual concentric injector"

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Morgan, Leigh C., Alan J. Wheatley, and Kevin D. Brundish. "Development of a Variable Fuel Placement Airblast Atomiser." In ASME Turbo Expo 2001: Power for Land, Sea, and Air. American Society of Mechanical Engineers, 2001. http://dx.doi.org/10.1115/2001-gt-0377.

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This paper presents the progress made on the development of a dual spray, direct injection airblast fuel nozzle capable of variable fuel placement. It is anticipated that by varying the fuel placement within the confines of a combustion chamber it will be possible to control localised flame ‘Fuel Air Ratio’ and thus extend both stability and emissions performance in respect of engine power range. The extension of combustion stability is particularly desirable to high pressure, temperature and turndown ratio aero engines where the ratio between maximum and flight idle fuel flows is extreme. Atomiser aerodynamics have been developed that produce two different airflow re-circulating regions within the combustor. A concentric fuel filmer feeds each of these regions. By staging the fuel into each flame re-circulation zone the variation of local ‘Fuel Air Ratio’ can be more accurately controlled. A combination of bench testing and CFD has been used to analyse and manipulate airflow distribution between swirlers to form the two distinct flame regions. The work is ultimately concerned with the rationalisation of airflow distribution and fuel placement to best fit the operational envelope of the engine. The variable placement fuel injector features three or more air swirlers (inner swirler, middle swirler and dome swirler) and two ‘airblast’ fuel filmers (pilot and main). The paper describes the progress made with a number of fuel injector configurations.
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Pearce, Kimberley Ann, Helge G. Skorve, and Morten Grini. "World's First Annular Safety Valve for Dual Concentric Water Injection." In SPE/IADC Drilling Conference. Society of Petroleum Engineers, 2007. http://dx.doi.org/10.2118/105489-ms.

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Pleshkov, Dmitry, Carlos Andres Corella Moya, Byron Ricardo Corella Moya, Angel Vicente Silva Ortiz, Luis Paredes, Augusto Huaca, Freddy Chicaiza, Gustavo Ariel Marin, Raul Armando Valencia Tapia, and Anur Kumar Rajain. "Disruptive Dumpflooding Completion, Case Study Ecuador." In Offshore Technology Conference Asia. OTC, 2022. http://dx.doi.org/10.4043/31533-ms.

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Abstract Most of the fields in Ecuador are considered "mature." Water injection is a well-known solution for mature fields. Water injection projects require a source of clean water. Traditionally, minimum specifications are achieved by surface treatment facilities. However, in the Ecuadorian Oriente Basin, the Hollin reservoir is an active aquifer with water meeting the requirements for use in waterflooding. But in other cases, water from production wells and from traditional surface facilities requires high investment costs because of associated facilities, chemical treatments, water production lines, and other requirements. A novel completion design has been developed. This proposed completion is called "modified dumpflooding" and represents a cost-effective solution for Ecuadorian mature fields. Dumpflooding is a modified version of dual concentric completion using most of its configuration pieces. It also takes advantage of extensive local experience in dual concentric completion design. Modified dumpflooding completion enables companies to use just one well for water production, injecting it into the depleted reservoir as a closed loop. Additionally, it helps to save costs in surface facilities by reducing human exposure to high pressure lines over large distances and eliminating operational expenditures for chemicals and equipment maintenance. Nodal analysis is foundational to helping companies understand how current design of waterflooding projects is behaving. It also provides a basis for mechanical configuration optimization to reduce bottlenecking points and improve completion performance.
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Al-Maqsseed, N., E. Anthony, R. Bhagavatula, C. Rodenboog, Euan Jamieson, Ajay Jha, Gong Hua, and Ghazi Al-Sharhan. "First Global Application of Simultaneous Injection & Production SIP Technology Using Dual Concentric Strings with ESP." In SPE Annual Technical Conference and Exhibition. Society of Petroleum Engineers, 2018. http://dx.doi.org/10.2118/191430-ms.

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Vasper, Adam C., and Ingvild Bakke Fagereng. "Temperature Specifications for CCUS Completions Equipment: Steady-State and Transient Thermal Simulations." In SPE EuropEC - Europe Energy Conference featured at the 83rd EAGE Annual Conference & Exhibition. SPE, 2022. http://dx.doi.org/10.2118/209637-ms.

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Abstract Different simulated injection scenarios can significantly cool carbon capture utilization and storage (CCUS)wells. Cases representing different scenarios were modeled to help determine appropriate temperature specifications for completions equipment in CCUS wells. Depleted reservoirs, in particular gas reservoirs, will not support a static column of liquid or dense-phase CO2 to surface at the initial reservoir pressure. During injection, unless there is significant friction or backpressure, the upper part of the well will be at low pressure, with CO2 in the gas phase. Injected, liquid CO2 will depressurize across the wellhead choke, or the upper tubing, resulting in significant cooling as the saturation curve is reached and the CO2 starts flashing. For steady-state injection across a narrow range of rates, a tapered or narrow completion string can be designed that provides sufficient friction pressure to keep the CO2 in the liquid phase. A portfolio or set of wells, potentially with different tubing sizes, will give more flexibility for managing injection rates. Transient scenarios such as injection startup or shutdown cause rapid changes in rate and can consequently induce severe thermal shocks. These cannot be completely prevented using only friction or passive downhole devices. Many completion options have been proposed to provide flexibility for injection rate changes and/or reservoir pressure increases. These include concentric or dual strings providing multiple flow paths with different flow areas and hence friction, downhole passive chokes, backpressure control valves, surface-operated downhole flow control valves, and various combinations of these and other technologies. Currently, the only methods to eliminate all the scenarios consideredmay be (active) backpressure control and surface-controlled downhole flow control valves. Whereas the transient effects are most severe in depleted reservoirs, they are also shown to occur in reservoirs approaching hydrostatic pressure. The most important component in the completion string is arguably the subsurface safety valve (SSSV). API 14B specifies a maximum leak rate for the closed SSSV. Following a blowout or depressurization event, a leak of high-pressure, liquid CO2 from below the SSSV to low-pressure, gas-phase CO2 above will cause localized cooling at the SSSV, in addition to that caused by the initial depressurization condition. Modeling included simulations of blowout and subsequent SSSV leakage phases for different periods of injection and hence reservoir cooldown. To quantify these effects, the work considered temperatures in the different radial sections of the well versus time and depth. Sensitivities on annulus fluid, reservoir properties including pressure and permeability, the rate of mass transfer between phases, and other variables were also investigated. Modeling was performed using a commercial dynamic multiphase flow simulator.
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Leon, Fernando, Angel Silva, Jorge Luis Villalobos, Ximena Guerrero, David Amores, Alejandro Villarreal, Dario Cuenca, et al. "Novel Dual Completion Architecture Improves Oil Production and Boosts Secondary Recovery with Minimal Surface Footprint." In SPE Annual Technical Conference and Exhibition. SPE, 2022. http://dx.doi.org/10.2118/210286-ms.

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Abstract The novel dual electric submersible pump (ESP) completion was designed to maximize oil recovery by improving waterflooding efficiencies while minimizing capital expenditures (capex) and surface facilities. The design enables the operator to produce oil and formation water from the same well. The injection of water, produced from the same oil producer, is part of a waterflooding project to boost secondary recovery. Based on the dual concentric completion (DCC) concept, this novel solution integrates an inverted flow architecture to provide the upper ESP with direct access to the lower reservoir zone, which is the water-producing zone. This single ESP is then used as the only equipment to lift the produced water and then provide sufficient pressure for direct injection into a neighboring well, without the need for surface treating and handling facilities. Oil production is lifted by the encapsulated lower ESP. The complete solution includes a monobore anchor with an automatic release tool to eliminate oil-zone damage during the completion phase and maximize water-zone productivity. The upper reservoir expected to produce approximately 700 BOPD with 1% water cut; after the successful implementation and commissioning of this novel architecture and its impact on the secondary recovery process, the recorded production reached more than 1,000 BOPD, with an overall 35% oil production increase in the field. Using a monobore anchor with an automatic release tool to perforate the lower sand allowed to combine the underbalance technique with clean perforations system and high impact penetration charges, which resulted in greater water zone productivity and improved pump efficiency, reducing power consumption by 33%. Considering that the project was implemented with a local diesel generator, the total CO2 emissions reduction was approximately 700 metric tons per year in just one well. Because the novel inverted DCC solution does not require the construction of traditional surface facilities for water injection, which include horizontal pumping systems (HPSs), capex was significantly reduced. In addition, because this solution was developed, designed, and implemented in far less time than a traditional method would have been, production was increased earlier than otherwise possible, helping the operator meet production targets and increase cash flow.
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