Journal articles: 'Oil flow visualization'

1

Lu, F. K. "Surface oil flow visualization." European Physical Journal Special Topics 182, no. 1 (April 2010): 51–63. http://dx.doi.org/10.1140/epjst/e2010-01225-0.

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Campbell, Bruce T., and Franklin M. Orr. "Flow Visualization for CO2/Crude-Oil Displacements." Society of Petroleum Engineers Journal 25, no. 05 (October 1, 1985): 665–78. http://dx.doi.org/10.2118/11958-pa.

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Abstract Results of visual observations of high-pressure CO2 floods are reported. The displacements were performed in two-dimensional (2D) pore networks etched in glass plates. Results of secondary and tertiary first-contact miscible displacements and secondary and tertiary multiple-contact miscible displacements are compared. Three displacements with no water present were performed in each of three pore networks:displacement of a refined oil by the same oil dyed a different color;displacement of a refined oil by CO2 (first-contact miscible); anddisplacement of a crude oil at a pressure above the minimum miscibility pressure. In addition, three tertiary displacements were performed in the same pore networks;displacement of the refined oil by water, followed by displacement by the same refined oil dyed to distinguish it from the original oil;tertiary displacement of the refined oil by CO2; andtertiary displacement of crude oil by CO2. In addition, recovery of oil from dead-end pores, with and without water barriers shielding the oil, was investigated. Visual observations of pore-level displacement events indicate that CO2 displaced oil much more efficiently in both first-contact and multiple-contact miscible displacements when water was absent. In tertiary displacements of a refined oil, CO2 effectively displaced the oil it contacted, but high water saturations restricted access of CO2 to the oil. The low viscosity of CO2 aggravated effects of high water saturations because the CO2 did not displace water efficiently. CO2 did, however, contact trapped oil by diffusing through water to reach, to swell, and to reconnect isolated droplets. Finally, CO2 displaced crude oil more efficiently than it did the refined oil in tertiary displacements. Differences in wetting behavior between the refined and crude oils appear to account for the different flow behavior. Introduction If high-pressure CO2 displaces oil in a one-dimensional (1D), uniform porous medium (in which the effects of viscous fingering are necessarily absent), the displacement efficiency is controlled by the phase behavior of the CO2/crude-oil mixtures. The conventional description of the effects of phase behavior was given by Hutchinson and Braun1 for vaporizing gas drives and was extended to CO2 systems by Rathmell et al.2 In a rigorous mathematical treatment of the flow of three-component mixtures. Helfferich3 proved that the displacement will develop miscibility if the oil composition lies outside the region of tie-line extensions on a ternary diagram. Helfferich's analysis was for 1D flows in which fluids are mixed well locally, and the effects of dispersion are absent. Sigmund et al.,4 Gardner et al.,5 and Orr et al.6 showed that results of slim-tube displacements, which are nearly 1D and come close to eliminating the effects of viscous instability, can be predicted quantitatively by 1D process simulations based on independent measurements of the phase behavior and fluid properties of the CO2/crude-oil mixtures. Thus there is good experimental confirmation that the simple theory of the effects of phase behavior on displacement performance describes accurately the behavior of flow in an ideal displacement, such as a slim tube. In a CO2 flood in reservoir rock, however, a variety of other factors will influence process performance. Because the viscosity CO2 is much lower than that of most oils, viscous instability will limit the sweep efficiency of the injected CO2. In addition, Gardner and Ypma7 predicted, based on 2D simulations of the growth of a viscous finger, that an interaction between viscous instability and phase behavior would lead to higher residual oil saturation in regions penetrated by a viscous finger. Pore-structure heterogeneity may also influence displacement efficiency. Spence and Watkins8 found that residual oil saturations after CO2 waterfloods increased as the heterogeneity of the core increased. Several investigators have reported that high water saturations can alter mixing between oil and injected solvent. Raimondi and Torcaso9 found, in displacements in Berea sandstone cores, that significant fractions of the oil phase could not be contacted by injected solvent when the water saturation was high. Thomas et al.10 reported that a portion of the nonwetting phase can exist in "dendritic" pores whose shapes were determined by the surrounding wetting phase. They argued that material in the dendritic pores mixed with fluid in the flowing fraction only by diffusion. Stalkup11 and Shelton and Schneider12 also investigated effects of mobile water saturations in miscible displacements. Stalkup found that the flowing fraction decreased as the water saturation increased. Shelton and Schneider reported that the presence of a second mobile phase slowed recovery of either phase, but the nonwetting phase was affected more strongly. In their tests, all of the wetting phase was recovered by a miscible displacement, but significant amounts of nonwetting phase remained unrecovered.

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KURATSUJI, Kazaki, Mutsuki SATAKE, and Akihiko AZETSU. "Visualization of Oil Film Flow Using Photochromism." Proceedings of Conference of Kanto Branch 2017.23 (2017): 603. http://dx.doi.org/10.1299/jsmekanto.2017.23.603.

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KITAJIMA, Ikkei, and Akihiko AZETSU. "Study on Flow Visualization of Oil Film." Proceedings of Mechanical Engineering Congress, Japan 2016 (2016): J0720202. http://dx.doi.org/10.1299/jsmemecj.2016.j0720202.

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YANAI, Eijiro, Naoto KASUYA, Syota KAI, and Akihiko AZETSU. "G071012 Study on Flow Visualization of Oil Filme." Proceedings of Mechanical Engineering Congress, Japan 2013 (2013): _G071012–1—_G071012–5. http://dx.doi.org/10.1299/jsmemecj.2013._g071012-1.

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AZETSU, Akihiko, Kenji SHIMIZU, and Genta KOBAYASHI. "G070064 Study on Flow Visualization of Oil Film." Proceedings of Mechanical Engineering Congress, Japan 2011 (2011): _G070064–1—_G070064–4. http://dx.doi.org/10.1299/jsmemecj.2011._g070064-1.

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SUGANUMA, Kentaro, Hoshio TSUJITA, Satoshi YAMAGUCHI, Akihiro YAMAGATA, and Natsuko MOTODA. "122 Oil Surface Flow Visualization in Radial Turbine." Proceedings of Conference of Tohoku Branch 2012.47 (2012): 50–51. http://dx.doi.org/10.1299/jsmeth.2012.47.50.

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AZETSU, Akihiko, and Ikkei KITAJIMA. "G0700603 Study on Flow Visualization of Oil Film : Photochromism of Oil." Proceedings of Mechanical Engineering Congress, Japan 2015 (2015): _G0700603——_G0700603—. http://dx.doi.org/10.1299/jsmemecj.2015._g0700603-.

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9

Xu, Jiu, and Pega Hrnjak. "Flow Visualization and Experimental Measurement of Compressor Oil Separator." SAE International Journal of Passenger Cars - Mechanical Systems 11, no. 5 (April 3, 2018): 377–88. http://dx.doi.org/10.4271/2018-01-0067.

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10

Su, Yaoxi. "Mechanism of sidewall effect studied with oil flow visualization." AIAA Journal 27, no. 12 (December 1989): 1828–30. http://dx.doi.org/10.2514/3.10344.

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11

Yokokawa, Yuzuru, Kazuomi Yamamoto, and Hiroshi Uchida. "W101 Fluorescent Oil Flow Visualization in Aircraft Research Experiment." Proceedings of the Fluids engineering conference 2009 (2009): 607–8. http://dx.doi.org/10.1299/jsmefed.2009.607.

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12

Bandarra Filho, Enio P., Lixin Cheng, and John R. Thome. "Flow boiling characteristics and flow pattern visualization of refrigerant/lubricant oil mixtures." International Journal of Refrigeration 32, no. 2 (March 2009): 185–202. http://dx.doi.org/10.1016/j.ijrefrig.2008.06.013.

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13

Feng, Wuheng, Yuxin Zhao, Qiancheng Wang, and Chenglong Wang. "Influence of the Reynolds Number on Transonic Tip Flow." International Journal of Aerospace Engineering 2020 (November 7, 2020): 1–11. http://dx.doi.org/10.1155/2020/8841093.

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The tip flows in modern gas turbines are primarily transonic under realistic conditions and significantly impact the overall thrust performance and safety of the turbines. This study is aimed at providing a deeper understanding of the mechanisms underlying and controlling the tip flow characteristics. Particle image velocimetry (PIV) and Schlieren and oil flow visualizations were performed to reveal the basic structure of the tip flow fields. A computational fluid dynamics model was developed, and the experimental results validated its accuracy. FLUENT 18.0 was employed to apply the Spalart-Allmaras turbulence model and perform two-dimensional calculations that furthered the investigation. The PIV and Schlieren visualization results indicated that the tip flow accelerated rapidly to the transonic level at the gap inlet separation when the gap pressure ratio exceeded 2.0. Furthermore, an oblique shock wave was generated when the transonic tip flow reattached and then reflected within the gap. The oil flow visualization provided the corresponding boundary layer behavior on the bottom wall. Additionally, the computation of the transonic tip flow with respect to various sizes and pressure values demonstrated that the Reynolds number is the key parameter that controls the gap flow field. The flow similarity existed as long as the Reynolds number remained constant. An in-depth analysis of the simulation improved the model performance at predicting the inlet separation size, discharge coefficient, and friction coefficient based on the Reynolds number. The study results provide a reference for the design and testing of engine blade gaps in real-world conditions.

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14

Li, Songyan, Zhaomin Li, and Zhuangzhuang Wang. "Experimental study on the performance of foamy oil flow under different solution gas–oil ratios." RSC Advances 5, no. 82 (2015): 66797–806. http://dx.doi.org/10.1039/c5ra08348f.

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The lower limit of solution gas–oil ratio for foamy oil from Carabobo reservoir was determined by sandpack and visualization experiments, and explained by interfacial tension, interfacial dilational viscoelasticity, oil viscosity and elastic energy.

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15

Azetsu, Akihiko, Ikkei Kitajima, and Kazaki Kuratsuji. "Development of a new visualization technique using photochromism for transport process of lubricating oil around the engine piston." International Journal of Engine Research 20, no. 7 (December 19, 2018): 777–87. http://dx.doi.org/10.1177/1468087418819229.

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This study proposes and experimentally validates a new method for the visualization of oil film flow. A photochromic dye is dissolved in the oil and an arbitrary spot of an oil film is illuminated with ultraviolet light, which makes a marker in the oil film via a photochromic reaction. The basic principle of the photochromic reaction and its application to flow visualization are described. The color density of the colored solution is quantified based on the absorbance calculated from images taken before and after coloring. The results confirm that the color density is proportional to the oil film thickness. The color density changes sufficiently slowly at room temperature to make it suitable as a marker for flow visualization. The characteristics of the coloring and fading reactions are examined. The results confirm that increase in the energy density of the ultraviolet light effectively increases the color density and that the optimal energy density of the ultraviolet light can be determined from a model formula for the coloring reaction. The color fading reaction at different temperatures is measured, and the temperature dependence of a solution of spiropyran and ester oil is quantified using an Arrhenius plot. Flow visualization is conducted in a 10- μm-thick flow channel with a complex shape. The test oil flowing through this channel is colored by the focused third harmonic of an Nd:YAG laser, and the flow velocity distribution is visualized using the proposed method. Finally, for experimental validation, the proposed method is used to visualize the movement of an oil film on the piston land of an optical engine. The proposed technique can be applied to investigate the dominant route of oil consumption and the physics involved.

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NIMURA, Tadashi, Toshifumi FUJIWARA, Michio UENO, and Koji NONAKA. "Wind Loads and Flow Visualization around an Oil Tanker Model." Journal of the Visualization Society of Japan 17, Supplement2 (1997): 217–20. http://dx.doi.org/10.3154/jvs.17.supplement2_217.

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17

Tsukiji, Tetsuhiro, Eishin Noguchi, and Futoshi Yoshida. "Development of Oil Hydraulic Components Using a Flow Visualization Technique." International Journal of Automation Technology 6, no. 4 (July 5, 2012): 410–17. http://dx.doi.org/10.20965/ijat.2012.p0410.

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In the present study, we succeed in observing cavitating flow near a notch (V-shaped groove) in a valve plate in an axial piston pump, and we improve an oil hydraulic ball valve, using the visualization technique. Our model of the axial piston pump, is designed to allow the jet flow near the notch and the cavitation cloud to be observed clearly from two directions using a high-speed video camera. Computational Fluid Dynamics (CFD) is employed to estimate the occurrence and the region of the cavitation cloud. It is found that our CFD method is very useful for estimating the region of the cavitation cloud. It is further found that adding notches serves to greatly reduce the cavitation region. Using a commercially available digital video camera, a high-speed video camera, and X-rays source, we also succeed in improving an oil hydraulic ball valve by preventing vibration, cavitation, and the noise.

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18

Jiao, Yun, Chengpeng Wang, Wenshuo Wang, and Keming Cheng. "Visualization and measurement of supersonic jet flow field evolution issuing from a rectangular nozzle with aft-deck." International Journal of Modern Physics B 34, no. 14n16 (June 1, 2020): 2040092. http://dx.doi.org/10.1142/s0217979220400925.

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An experimental study is reported of supersonic jet surface flow structure visualization and wall shear stress field measurement issuing from a rectangular nozzle with aft-deck. The near-field surface flow structures evolution from over-expansion to under-expansion with the increase of nozzle pressure ratio (NPR) are successfully captured by surface oil flow visualization and shear sensitive liquid crystal coating (SSLCC) technique. The quantitative measurement result of shear stress vector field obtained by SSLCC shows that shear stress directions change significantly across the shock wave and expansion fans, while the magnitudes of shear stress have no obvious changes. Surface streamlines calculated by SSLCC image keep great consistency with the streamlines visualized using oil flow technique, which demonstrates the accuracy and potential application of SSLCC in supersonic jet surface flow visualization.

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&NA;. "ANTITHROMBOGENIC SECONDARY FLOW ANALYSIS FOR BLOOD PUMPS WITH FLOW VISUALIZATION OIL FILM METHOD." ASAIO Journal 44, no. 2 (March 1998): 51A. http://dx.doi.org/10.1097/00002480-199803000-00188.

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20

Kaneko, S., and S. Obara. "Experimental Investigation of Mechanism of Lubrication in Porous Journal Bearings: Part 1—Observation of Oil Flow in Porous Matrix." Journal of Tribology 112, no. 4 (October 1, 1990): 618–23. http://dx.doi.org/10.1115/1.2920306.

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The oil flow in the porous matrix is experimentally investigated to explicate the mechanism of lubrication in the porous journal bearings. To visualize the flow in the porous matrix, a simplified model is used for the test bearing, whose matrix is composed of packed glass spheres having small uniform diameter. A dye-injection method is used for visualization. It is observed that there exists a circulation of oil through the porous matrix and this flow contributes to the lubrication in the porous bearings. The flow pattern is dependent on the lubrication conditions. Under hydrodynamic lubrication conditions, the oil in the porous matrix flows away from the position of the load line towards the unloaded region. However under boundary lubrication conditions, when the oil feed pressure is negligibly small, most of the oil in the porous matrix flows toward the region where the oil film pressure would take the minimum.

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21

Yu, Feng, and Yong Yin. "Oil Spill Visualization Based on the Numeric Simulation of Tidal Current." International Journal of Virtual Reality 8, no. 2 (January 1, 2009): 71–74. http://dx.doi.org/10.20870/ijvr.2009.8.2.2727.

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This paper proposes an approach to implement the 3D visualization of oil spill based on tidal hydrodynamic model. It simulates tidal current of M2 component tide in Jiaozhou Bay. The simulation results conform to the tidal theory and probably conform to the flow measurement report of crude oil pier Phase III at Qingdao Harbor. Based on tidal current and eye-point related adaptive ocean surface mesh model, by analyzing the drift and diffusion mathematical models of oil spill on the sea, the dynamic visualization of drift and diffusion course of oil on the sea were implemented, the visualization result is satisfactory.

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Ristic, Slavica. "A - a view in the invisible." Theoretical and Applied Mechanics 40, no. 1 (2013): 87–119. http://dx.doi.org/10.2298/tam1301087r.

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Flow visualization is an important topic in, experimental and computational fluid dynamics and has been the subject of research for many years. This paper presents an overview of flow visualization techniques. The physical basis and applications of different visualization methods for subsonic, transonic and supersonic flow in wind and water tunnels are described: direct injection methods, (smoke, dye, fog and different small particles), gas and hydrogen bubbles, , flow visualization by tufts, oil, liquid crystals, pressure and temperature sensitive paints, shadow, schlieren, interferometry, Laser Doppler Anemometry, Particle Image Velocimetry and other special techniques. Almost all presented photos have been recorded during tests in laboratories of MTI Belgrade.

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Lee, In-seop, and Kee-yong Hong. "Flow visualization applied to oil flow of suction muffler of a small refrigeration compressor." Journal of the Visualization Society of Japan 15, Supplement1 (1995): 343–46. http://dx.doi.org/10.3154/jvs.15.supplement1_343.

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24

Tao, Y., R. Sakidja, and S. Kou. "Computer simulation and flow visualization of thermocapillary flow in a silicone oil floating zone." International Journal of Heat and Mass Transfer 38, no. 3 (February 1995): 503–10. http://dx.doi.org/10.1016/0017-9310(94)00180-4.

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25

Guerrero, Francy, Jonathan Bryan, and Apostolos Kantzas. "Visualization of Chemical Heavy Oil EOR Displacement Mechanisms in a 2D System." Energies 14, no. 4 (February 11, 2021): 950. http://dx.doi.org/10.3390/en14040950.

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This study aims to develop a visual understanding of the macro-displacement mechanisms associated with heavy oil recovery by water and chemical flooding in a 2D system. The sweep efficiency improvements by water, surfactant, polymer, and surfactant-polymer (SP) were evaluated in a Hele-Shaw cell with no local pore-level trapping of fluids. The results demonstrated that displacement performance is highly correlated to the mobility ratio between the fluids. Surfactant and water reached similar oil recovery values at similar mobility ratios; however, they exhibited different flow patterns in the 2D system—reductions in IFT can lead to the formation of emulsions and alter flow pathways, but in the absence of porous media these do not lead to significant improvements in oil recovery. Polymer flooding displayed a more stable front and a higher reduction in viscous fingering. Oil recovery by SP was achieved mostly by polymer rather than due to the effect of the surfactant. The surfactant in the SP slug washed out residual oil in the swept zone without increasing the swept area. This shows the impact of the surfactant on reducing the oil saturation in water-swept zones, but the overall oil recovery was still controlled by the injection of polymer. This study provides insight into the fluid flow behavior in diverging flow paths, as opposed to linear core floods that have limited pathways. The visualization of bulk liquid interactions between different types of injection fluids and oil in the Hele-Shaw cell might assist in the screening process for new chemicals and aid in testing the production process.

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OCHIAI, Masayuki, Takashi KOMATSU, Takaaki ISEYAMA, and Hiromu HASHIMOTO. "1305 Flow visualization in journal sliding bearing with supply oil groove." Proceedings of the Machine Design and Tribology Division meeting in JSME 2014.14 (2014): 83–84. http://dx.doi.org/10.1299/jsmemdt.2014.14.83.

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Xu, Jiu, and Pega Hrnjak. "Oil flow at the scroll compressor discharge: visualization and CFD simulation." IOP Conference Series: Materials Science and Engineering 232 (August 2017): 012051. http://dx.doi.org/10.1088/1757-899x/232/1/012051.

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28

Eggleston, D. M., and K. Starcher. "A Comparative Study of the Aerodynamics of Several Wind Turbines Using Flow Visualization." Journal of Solar Energy Engineering 112, no. 4 (November 1, 1990): 301–9. http://dx.doi.org/10.1115/1.2929938.

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Flow visualization techniques were used to study the flows over the Enertech 21-5, Carter 25, and Enertech 44-50. Despite centrifugal effects superimposed on the aerodynamics, tufting (gross aerodynamic behavior) and oil flow (average boundary layer behavior), tests reveal the nature and many of the details of the flows involved. Results were compared to expected flow patterns based on angles of attack calculated from the PROPPC code. Chord Reynolds numbers ranged between 75,000 (Enertech 21-5) to 1,340,000 (Enertech 44-50). The typical low Reynolds number flow characteristics of these airfoils, including laminar separation bubbles, turbulent reattachment, and complete separation were observed. Full or partial reattachment due to tower shadow was observed on each machine. Spanwise flow was observed near the leading edge of the Enertech 21-5. Cyclic radial flow from tower dam effect was also noted.

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Jiao, Yun, and Chengpeng Wang. "Visualization of separation and reattachment in an incident shock-induced interaction." Proceedings of the Institution of Mechanical Engineers, Part G: Journal of Aerospace Engineering 235, no. 12 (March 11, 2021): 1706–16. http://dx.doi.org/10.1177/0954410020983495.

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An experimental study is conducted on the qualitative visualization of the flow field in separation and reattachment flows induced by an incident shock interaction by several techniques including shear-sensitive liquid crystal coating (SSLCC), oil flow, schlieren, and numerical simulation. The incident shock wave is generated by a wedge in a Mach 2.7 duct flow, where the strength of the interaction is varied from weak to moderate by changing the angle of attack α of the wedge from 8° and 10° to 12°. The stagnation pressure upstream was set to approximately 607.9 kPa. The SSLCC technique was used to visualize the surface flow characteristics and analyze the surface shear stress fields induced by the initial incident shock wave over the bottom wall and sidewall experimentally which resolution is 3500 × 200 pixels, and the numerical simulation was also performed as the supplement for a clearer understanding to the flow field. As a result, surface shear stress over the bottom wall was visualized qualitatively by SSLCC images, and flow features such as separation/reattachment and the variations of position/size of separation bubble with wedge angle were successfully distinguished. Furthermore, analysis of shear stress trend over the bottom wall by a hue value curve indicated that the relative magnitude of shear stress increased significantly downstream of the separation bubble compared with that upstream. The variation trend of shear stress was consistent with the numerical simulation results, and the error of separation position was less than 2 mm. Finally, the three-dimensional schematic of incident shock-induced interaction has been achieved by qualitative summary by multiple techniques, including SSLCC, oil flow, schlieren, and numerical simulation.

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SHINTANI, Yoshitomo, Ryosuke MATSUMOTO, Masaki OKADA, Isao ISHIHARA, Mamoru OZAWA, and Keizo IMAHORI. "Flow Visualization of 3-D Flow Structure in Boiler Tube Bank by Oil-Lampblack Method." Journal of the Visualization Society of Japan 20, no. 2Supplement (2000): 97–100. http://dx.doi.org/10.3154/jvs.20.2supplement_97.

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31

Guiming, Tang. "Surface oil flow technique and liquid crystal thermography for flow visualization in impulse, wind tunnels." Acta Mechanica Sinica 10, no. 3 (August 1994): 220–26. http://dx.doi.org/10.1007/bf02487610.

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32

Bra¨unling, W., A. Quast, and H. J. Dietrichs. "Detection of Separation Bubbles by Infrared Images in Transonic Turbine Cascades." Journal of Turbomachinery 110, no. 4 (October 1, 1988): 504–11. http://dx.doi.org/10.1115/1.3262224.

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In a test facility for straight cascades, equipped with profiles designed for a highly loaded gas turbine rotor of a high-pressure stage, experiments were conducted to clarify some effects of shock wave–boundary layer interactions. The specific aim was to determine both the position and strength of compression shocks originating from profile wake flows and the position and extent of separation bubbles. The latter are most often detected by visualization methods like surface oil flow patterns or Schlieren photographs, as well as by typical properties in wall pressure distribution curves. In addition, the infrared image technique, which has found many applications in a wide range of technical activities in the recent years, may also be used. Compared with other methods, this technique has distinct advantages in fluid mechanics applications. The whole model can be observed without disturbing the boundary layer by tappings, measuring materials, or probes. Some typical infrared images are presented and interpreted using results of pressure distribution measurements, hot-film measurements, and surface oil flow visualizations.

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Hamkins, Christopher P., and Stephan Bross. "Use of Surface Flow Visualization Methods in Centrifugal Pump Design." Journal of Fluids Engineering 124, no. 2 (May 28, 2002): 314–18. http://dx.doi.org/10.1115/1.1470477.

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Surface flow patterns generated with oils or oil paint have been used in centrifugal pump design for many years. Here it is shown how modern image analysis methods allow quantitative predictions of the corresponding pressure distribution by analyzing surface flow patterns. Further, the surface flow patterns can be used to confirm computational fluid dynamics (CFD) results, improve their boundary conditions and determine their limits of validity. The authors see the need for a new type of boundary condition for CFD packages, in which a measured flow pattern could be used as “input.”

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Jung, Ho-Yun, Yoon-Hwan Choi, Yeon-Won Lee, and Deog-Hee Doh. "Numerical Visualization of Fluid Flow and Filtration Efficiency in Centrifugal Oil Purifier." Journal of the Korean Society of Marine Engineering 34, no. 1 (January 31, 2010): 84–91. http://dx.doi.org/10.5916/jkosme.2010.34.1.084.

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35

Al-Shalabi, E. W., and B. Ghosh. "Flow visualization of fingering phenomenon and its impact on waterflood oil recovery." Journal of Petroleum Exploration and Production Technology 8, no. 1 (March 23, 2017): 217–28. http://dx.doi.org/10.1007/s13202-017-0336-0.

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He, Binhua, Guoshuai Li, Fangqi Zhou, Dawei Liu, and Xie Xiang. "Application of colour fluorescent oil flow visualization for a high speed cavity." Journal of Physics: Conference Series 1786, no. 1 (February 1, 2021): 012049. http://dx.doi.org/10.1088/1742-6596/1786/1/012049.

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Tian, Qing, Roger L. Simpson, and Genglin Tang. "Flow visualization on the linear compressor cascade endwall using oil flows and laser Doppler anemometry." Measurement Science and Technology 15, no. 9 (August 18, 2004): 1910–16. http://dx.doi.org/10.1088/0957-0233/15/9/031.

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38

Fan, Yiqiang, Kexin Gao, Jie Chen, Wengang Li, and Yajun Zhang. "Low-cost PMMA-based microfluidics for the visualization of enhanced oil recovery." Oil & Gas Science and Technology – Revue d’IFP Energies nouvelles 73 (2018): 26. http://dx.doi.org/10.2516/ogst/2018026.

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About one-third of the crude oil is trapped inside the pores of the carbonate and sandstone after the primary and secondary oil recovery, various methods have been used for the flooding of the trapped crude oil. Due to the opaque nature of the sandstone and shale, the visualization of the fluid flow inside the porous structure conventionally involved the use of very sophisticated equipment like X-ray computed microtomography. In this approach, a low-cost method for the mimic of porous structure for the enhanced oil recovery is proposed using the polymethyl methacrylate (PMMA)-based microfluidic devices with the laser ablated microstructures, where the microstructure is the replica of a real rock fracture. Since the PMMA is optically clear in the visible range, the detailed fluid flow inside the porous structure could be obtained for a better understanding of the liquid front propagation and rheology in the pore-scale. The effect of water flooding is also tested with the proposed microfluidic devices under various flooding rates for the demonstration of oil recovery enhancement with the proposed technology.

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Bora, R., B. B. Maini, and A. Chakma. "Flow Visualization Studies of Solution Gas Drive Process in Heavy Oil Reservoirs Using a Glass Micromodel." SPE Reservoir Evaluation & Engineering 3, no. 03 (June 1, 2000): 224–29. http://dx.doi.org/10.2118/64226-pa.

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Summary A series of flow visualization experiments was carried out to examine the pore scale behavior of the solution gas drive process in heavy oil reservoirs. The main objective was to testify several speculative theories that had been put forward to explain the anomalous production behavior of heavy oil reservoirs producing under the solution gas drive process. Contrary to previous postulations, the asphaltene constituents did not appear to play a significant role in the nucleation and stabilization of the gas bubbles that evolved during the solution gas drive process. Experimental evidence also suggests that the production of heavy oil is not accompanied by a large population of microbubbles. These observations suggest that the production enhancement in the solution gas process in heavy oil reservoirs may be related to other mechanisms such as viscous coupling effects, sand production, wormhole effects, etc. Introduction Primary production of heavy oil reservoirs operating under the solution gas drive mechanism exhibits an unexpectedly higher primary recovery with a slower pressure decline rate, lower than expected gas oil ratios, and higher oil production rates. These reservoirs which are prolific during the primary production phase have shown very poor response to secondary recovery techniques, such as thermal recovery. Ongoing observations in the fields 1–4 and preliminary observations in laboratories 5–7 strongly suggest that the cold production process of heavy oil reservoirs by the solution gas drive process involves a multitude of effects. A detailed analysis of such unusual production behavior was first provided by Smith.1 He suggested that the solution gas drive in heavy oil reservoirs involves simultaneous flow of oil and gas in the form of microbubbles. Following this, the flow behavior of such gas-oil dispersions has been the subject of several investigators and considerable speculation.2–9 However, the solution gas mechanism in heavy oil reservoirs remains controversial and poorly understood. Background In the solution gas drive process, the main source of energy driving the oil towards the wellbore is the evolution and expansion of the gas bubbles initially dissolved in the oil. The role of the gas bubbles in the oil displacement process has been studied for a long time.10--16 The first visual studies of the behavior of the solution gas process at the microscopic level was performed by Chatenever et al.14 using thin glass bead packings and thin sections of natural sandstone and limestone. With the advent of glass micromodels, flow visualization studies were conducted to examine the microscopic behavior of the solution gas drive process.17–22 All these studies provided a direct observation of pore level events. However, a comprehensive understanding of the pore scale physics in the solution gas drive process has not yet been attained. Moreover, recent observations in the field led to revised thinking of the mechanisms involved in the solution gas drive process in heavy oil reservoirs. The flow of heavy oil under the solution gas drive process appears to be more complex than what is expected from conventional solution gas drive theories. None of the previous studies focused on the behavior of the solution gas process in heavy oil reservoirs. To acquire an improved understanding of the solution gas drive mechanisms, it is necessary to consider the pore scale physics. Most of the questions concerning nucleation, growth, coalescence, and flow of the gas bubbles dispersed in oil can be answered only by direct examination of individual pore scale events. Although it is not possible to visually examine the processes occurring at the pore level in actual reservoir rocks, a very close approximation can perhaps be achieved in a micromodel. Micromodels provide a very convenient means of directly observing the formation, growth, flow, and trapping of gas bubbles. The main objective of this work was to carry out a series of flow visualization experiments, using a high pressure etched glass micromodel, to make a detailed investigation of the effects of asphaltene particles, pressure depletion rates, and sand wettability on the pore level flow mechanisms in the solution gas drive process. To the best of our knowledge, there has been no such systematic investigation of pore scale physics of the solution gas drive process in heavy oil reservoirs. The applications and technical contributions of such a study include the following:an improved understanding of the solution gas drive mechanism in heavy oil reservoirs,planning optimum development strategies for heavy oil reservoirs, andunderstanding of the condition of the reservoir at the end of the primary production phase which is helpful for developing an effective follow-up secondary recovery technique. Micromodel Apparatus The experimental setup is shown schematically in Fig. 1. The heart of the test rig is the high pressure etched glass micromodel. Conceptually, it is simple in design. Two glass plates were held together by overburden pressure inside a windowed pressure vessel. One of the glass plates had a detailed flow pattern chemically etched onto it, the other plate was unetched and had parallel sides. The flow pattern used in this work is displayed in Fig. 2. Here, the black dots represent sand grains while the white area represents the flow channels. The center to center distance between adjoining "sand grains" was 500 µm and the diameter of each dot was 334 µm. The average depth of etched flow channels was about 50 µm. The pore volume within the boundaries of the etched pattern was approximately 75 µL. The etched flow patterns were illuminated with high intensity halogen light bulbs underneath the bottom window of the pressure vessel. The overburden pressure in the pressure vessel was maintained at 600 psi (4.14 MPa) throughout the entire study.

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Saad, Mohd Rashdan, Azam Che Idris, and Konstantinos Kontis. "Flow Diagnostics in Shock Wave-Boundary Layer Interaction Experiments in Hypersonic Flow." Applied Mechanics and Materials 660 (October 2014): 669–73. http://dx.doi.org/10.4028/www.scientific.net/amm.660.669.

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Shock Wave-Boundary Layer Interaction (SBLI) is a phenomenon occurring in high-speed propulsion systems that is highly undesirable. Numerous methods have been tested to manipulate and control SBLI which includes both active and passive flow control techniques. To determine the improvements brought by the flow control techniques, advanced and state-of the-art flow diagnostics and experimental techniques are required, especially when it involves high-speed flows. In this study, a number of advanced flow diagnostics were employed to investigate the effect of micro-vortex generators in controlling SBLI in Mach 5 such as Pressure Sensitive Paints (PSP), Particle Image Velocimetry (PIV), schlieren photography and oil-flow visualization. The flow diagnostics successfully visualized the boundary layer separation and also the improvements brought by the micro-vortex generators.

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Li, Quan Hou, Qun Peng, and Peng Li Wang. "Two Basic Issues in the Development of Oil-Field Visualization." Applied Mechanics and Materials 340 (July 2013): 226–29. http://dx.doi.org/10.4028/www.scientific.net/amm.340.226.

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It can be seen from the analysis of two issues, which we have met during the research on visualization of oil-field development, that it is difficult to deal with the division of flowing units in reservoirs with various methods, such as index method of zone of flow, sedimentalogical method. And logging data is just the reflection for the information of reservoirs. However we can effectively improve the accuracy degree of division of flowing units with the method of fundamental interpretation units in the logging data interpretation. This essay points out five directions of the study on the regular patter of remaining oil distribution and make it sure that only by combining statistic and dynamic method can we confirm how the remaining oil distribute and know how to make it quantified.

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Patil, Manthan, Rajesh Gawade, Shubham Potdar, Khushabu Nadaf, Sanoj Suresh, and Devabrata Sahoo. "Effect of vortex generator on the flow field over a conventional delta wing in subsonic flow condition at higher angles of attack." FME Transactions 49, no. 2 (2021): 395–400. http://dx.doi.org/10.5937/fme2102395p.

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Flow over a conventional delta wing has been studied experimentally at a subsonic flow of 20 m/sec and the flow field developed at higher angle of attack varying from 10° to 20° has been captured. A vortex generator is mounted on the leeward surface of the delta wing and its effect on the flow field is studied. The set of wing tip vortices generated over the delta wing is captured by the oil flow visualization and the streamline over the delta wing surface captured with and without a vortex generator are compared. Based on the qualitative results, the effect of the vortex generator on the lift coefficient is anticipated. Further, force measurement is carried out to quantitatively analyze the effect of vortex generator on the lift and drag coefficient experienced by the delta wing and justify the anticipation made out of the qualitative oil flow visualization tests. In the present study, the effect of mounting of a vortex generator is found to be minimal on the lift coefficient experienced by the delta wing. However, a significant reduction in the drag coefficient with increase in angle of attack was observed by mounting a typical vortex generator.

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Wu, Feng, Cong Yao, Linlin Cong, and Yanping Xi. "Pore-scale gas–water flow in rock: Visualization experiment and simulation." Open Geosciences 12, no. 1 (July 30, 2020): 532–46. http://dx.doi.org/10.1515/geo-2020-0105.

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AbstractThe characteristics of pore-scale two-phase flow are of significance to the effective development of oil and gas resources, and visualization has gradually become one of the hot spots in the research of pore-scale two-phase flow. Based on the pore structure of rock, this research proposed a microscopic glass etching displacement experiment and a Navier–Stokes equation based finite element simulation to study the pore-scale gas–water two-phase flow. Then, this research conducted the proposed methods on the type I, type II and type III tight sandstone reservoirs in the Penglaizhen Formation of western Sichuan Basin, China. Results show that the outcomes of both the microscopic glass etching displacement experiment and the finite element simulation are by and large consistent. The water distributed in the large pores is displaced, and the trapped water mainly exists in the area induced by flow around high-permeability pores, perpendicular pores and disconnected ends of pores. The microscopic glass etching displacement experiment is conducive to better observing the phenomenon of a viscous finger-like breakthrough and air jumps in migration flows in narrow throats, while the finite element simulation has the advantages of cost effectiveness, easy operation and strong experimental reproducibility.

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Gopal, M., and W. P. Jepson. "The Study of Dynamic Slug Flow Characteristics Using Digital Image Analysis—Part I: Flow Visualization." Journal of Energy Resources Technology 120, no. 2 (June 1, 1998): 97–101. http://dx.doi.org/10.1115/1.2795032.

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This paper reports the application of novel, digital image analysis techniques in the study of slug flow characteristics, under dynamic conditions in two-phase gas-liquid mixtures. Water and an oil of viscosity 18 cP were used for the liquid phase and carbon dioxide was used for the gas phase. Flow in a 75-mm i.d., 10-m long acrylic pipeline system was studied. Images of slugs were recorded on video by S-VHS cameras, using an audio-visual mixer. Each image was then digitized frame-by-frame and analyzed on a SGI™ workstation. Detailed slug characteristics, including liquid film heights, slug translational velocity, mixing length, and, slug length, were obtained.

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ANYOJI, Masayuki, Keigo SIMIZU, Takuji Nakajima, Satoshi SEKIMOTO, and Kozo FUJII. "Visualization of Flow around Vehicle using Global Luminescent Oil-Film Skin-Friction Meter." Proceedings of Mechanical Engineering Congress, Japan 2017 (2017): J0510202. http://dx.doi.org/10.1299/jsmemecj.2017.j0510202.

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Er, V., and T. Babadagli. "Miscible Interaction Between Matrix and Fracture: A Visualization and Simulation Study." SPE Reservoir Evaluation & Engineering 13, no. 01 (February 4, 2010): 109–17. http://dx.doi.org/10.2118/117579-pa.

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Summary CO2 injection has been applied in naturally fractured reservoirs (NFRs) for the purpose of enhanced oil recovery (i.e., the Wey-burn and Midale fields, Canada; the Wasson and Slaughter fields, USA; and the Bati Raman field, Turkey). The matrix part of these types of reservoirs could potentially be a good storage medium as well. Understanding the matrix/fracture interaction during this process and the dynamics of the flow in this dual-porosity system requires visual analyses. We mimicked fully miscible CO2 injection in NFRs using 2D models with a single fracture and oil (solute)/hydrocarbon solvent pairs. The focus was on the visual pore-scale analysis of miscibility interaction, breakthrough of solvent through fracture, transfer between matrix and fracture, and the dynamics of miscible displacement inside the matrix. First, matrix/fracture interaction was studied intensively using 2D glass-bead models experimentally. The model was prepared using acrylic sheets and glass beads saturated with oil as a porous medium while a narrow gap of 1-mm size containing filter paper served as a fracture. The first contact miscible solvent (pentane) was injected into the fracture, and the flow distribution was monitored using an image-acquisition and -processing system. The produced solvent and solute were continuously analyzed for compositional study. The effects of several parameters, such as flow rate, viscosity ratio (oil/solvent), and gravity, were studied. Next, the process was modeled numerically using a commercial compositional simulator, and the saturation distribution in the matrix was matched to experimental data. The key parameters in the matching process were the effective diffusion coefficients and the longitudinal and the transverse dispersivities. The diffusion coefficients were specified for each fluid, and dispersivities were assigned into gridblocks separately for the fracture and the matrix.

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Kim, Pan Soo, and James L. White. "Flow Visualization of Intermeshing and Separated Counter-Rotating Rotor Internal Mixer." Rubber Chemistry and Technology 67, no. 5 (November 1, 1994): 880–91. http://dx.doi.org/10.5254/1.3538719.

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Abstract A flow visualization investigation of material motions and compounding in an internal mixer with intermeshing rotors is described. Rotors based on the design of R. T. Cooke of Francis Shaw and Company are used. Compared with separated rotor designs developed by F. H. Banbury, the distinctive feature is the passage of the rubber and compounding ingredients through the calendering gap between the rotors during mixing. The intermeshing rotors were found to rapidly circulate the materials from rotor to rotor around the mixing chamber and to more rapidly incorporate carbon black and oil relative to double-flighted separated rotors.

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Cheng, Sun-Wen, and Wen-Jei Yang. "Hysteresis in Oil Flow through a Rotating Tube with Twin Exit Branches." International Journal of Rotating Machinery 3, no. 4 (1997): 249–58. http://dx.doi.org/10.1155/s1023621x97000237.

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Oil enters a horizontal rotating tube through a radially-attached duct at one end. The tube with the other end closed is attached with radial twin exit branches permitting oil to exit into open air. Air begins to enter through one of the two branches into the tube when its rotational speed reaches certain critical values. An experimental study is performed to investigate this air-oil two-phase flow behavior. Both the tube and the branches are transparent to allow illumination and flow visualization during spin-up and spin-down processes. The branch-totube diameter ratio, rotational speed, and oil flow rate are varied. Changes in oil flow rates are measured as a function of rotational speed. A comparison is made between cases of a varying total oil flow rate due to rotation effects and a constant one under control. It is disclosed that cavitation in oil flow is induced by air entering the branches opposite to the ejecting oil flow. Subsequently air bubbles progress in the tube. The origin of this intrusion depends on the hydraulic head loss of the piping system. This study can be applied to oil lubrication analysis of rotating machinery, such as automotive transmission lines.

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Firoozabadi, Abbas, and Andrew Aronson. "Visualization and Measurement of Gas Evolution and Flow of Heavy and Light Oil in Porous Media." SPE Reservoir Evaluation & Engineering 2, no. 06 (December 1, 1999): 550–57. http://dx.doi.org/10.2118/59255-pa.

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Summary In a number of experiments, the efficiency of solution-gas drive for both light and heavy oils was studied. In these experiments a special coreholder was used to visually observe the formation of gas bubbles on the rock surface of a Berea core and the production from the core outlet. The results from all the experiments reveal that the critical gas saturation for three hydrocarbon liquids; 1. a light model oil, 2. an 11-API gravity oil, and 3. a 35-API gravity oil, does not exceed 3%. However, the gas mobility for the heavy oil is very low and for the light model oil very high. Consequently, solution-gas drive for a heavy oil of 11-API gravity is more efficient than for a light oil. Introduction Solution-gas drive is a basic recovery mechanism. The two parameters that affect the efficiency of this process are: critical gas saturation, and mobility of the gas and liquid phases. A high critical gas saturation implies a high recovery; a 30% critical gas saturation would result in 30% oil recovery provided the oil shrinkage is negligible. On the other hand, a low critical gas saturation does not necessarily imply a low recovery; a low gas mobility or a high liquid mobility would result in high recovery. Generally, solution-gas drive may not be efficient for very light oils. Factors which are believed to contribute to the low recovery are low critical gas saturation and high gas mobility. However, for a heavy oil, the recovery in solution-gas drive could be high either when the critical gas saturation is high or when the gas mobility is low and the liquid mobility is high. One purpose of this paper is to understand solution-gas drive for both light and heavy oils. Solution-gas drive is initiated with bubble nucleation, where at some critical supersaturation pressure (the pressure at which gas evolves from the supersaturated liquid) below the bubblepoint pressure, the formation of gas bubbles occurs. The bubbles may form instantaneously or according to the progressive nucleation theory.1 In progressive nucleation, the rate of bubble formation is related to the supersaturation. Recently, based on theoretical analysis, we have postulated that bubble nucleation in porous media can be an instantaneous nucleation process; all bubbles form instantaneously at the critical supersaturation pressure.1 Another objective of this work is to establish experimentally the instantaneous nature of nucleation in porous media. It has been known for some time that a number of heavy oil reservoirs in Canada (viscosity in the range of 200 to 20,000 cp) have high recovery efficiencies—around 15% to 20% by primary depletion.2,3 The high recovery occurs in the absence of gravity drainage and water drive. A number of authors have made attempts to explain the high recovery from heavy oil reservoirs. In an earlier paper, Smith2 hypothesized that solution-gas drive in heavy oil reservoirs is a two-phase flow, with the gas in the form of tiny bubbles moving with oil. Based on the work of Ward et al.,4 Smith argued that the radius of a stable bubble for a finite volume should be much smaller than the average pore throat. Ward et al.4 had estimated that for a bubble density of 103 cm3, the stable bubble may have a radius of 40 µm. These bubble densities and stable sizes may not apply to a heavy oil in porous media. Further theoretical work is needed to establish the bubble density and stable bubble size for heavy oils. In a later attempt, Islam and Chakma5 used both a long capillary tube and a horizontal core packed with unconsolidated sand to study mechanisms of bubble flow in heavy oil reservoirs. They used Dow Corning oils of 10, 1,000, and 5,000 cp viscosity and heavy oils to conduct flow experiments by simultaneous injection of gas bubbles and liquid. These experiments revealed that bubbles in a flowing stream of a viscous fluid will reduce the apparent viscosity. Islam and Chakma suggested a gas-oil relative permeability with a critical gas saturation of 40%. In-situ gas bubble formation and injection of gas bubbles in a liquid phase are fundamentally different processes. The work of these authors may not directly apply to solution-gas drive in heavy oil reservoirs. In a more recent study, Maini et al.,6 conducted many experiments using unconsolidated sand and heavy oils to study solution-gas drive. A 2-m long sand pack was employed by these authors. The recovery factor was obtained by dropping the pressure suddenly at the core outlet from a saturation pressure of some 700 psi to atmospheric pressure. More than 20% of the original heavy oil was produced in the primary depletion process. As has been observed by Islam and Chakma5 and others,1 a sudden drop in pressure may result in a higher recovery than a gradual pressure drop. From a number of tests, Maini et al. concluded that the critical gas saturation for the formation of a continuous gas phase could be about 40%. The critical gas saturation for heavy oils in the work of Islam and Chakma et al., and Maini et al., are much higher than the values for light oils.7 The above brief review reveals that further work is needed to understand the solution-gas drive in heavy oil reservoirs. The main objectives of this study are to: resolve the issue of very high critical gas saturations; find out whether tiny gas bubbles move with the oil phase; and determine the nature of bubble nucleation and bubble density and to better understand the efficiency of solution-gas drive for heavy oils in porous media. In this work, experiments with both light and heavy oils are performed in order to compare the solution-gas drive for light and heavy oils. A new visual coreholder is used to visually observe the appearance and flow of the gas phase. Experiment A schematic of the experimental apparatus is shown in Fig. 1. The setup, with slight differences, was used for the three sets of experiments. The main components of the apparatus include: the visual coreholder, a high pressure chromatography pump, pressure transducers, a system for providing a constant temperature of 77°F (±0.3°F) and a video recording system. The specially designed visual coreholder consists of an 8 in. long, 2 in. diameter Berea sandstone core (pore volume˜95 cm3, permeability˜500 md), capped at either end with a plexiglass cap (the top cap was machined with a dead end for trapping gas evolved from the core) and sealed with a heat-shrunk teflon sleeve. Surrounding the core is a water-filled translucent chamber, which is pressurized and acts as an overburden sleeve. Plumbed to the coreholder is a constant flow/pressure pump. The pump is used both for saturating the core system and for pressure decline through volume expansion.

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Eide, Øyvind, Martin A. Fernø, Zachary Alcorn, and Arne Graue. "Visualization of Carbon Dioxide Enhanced Oil Recovery by Diffusion in Fractured Chalk." SPE Journal 21, no. 01 (February 18, 2016): 112–20. http://dx.doi.org/10.2118/170920-pa.

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Summary This work demonstrates that diffusion may be a viable oil-recovery mechanism in fractured reservoirs during injection of carbon dioxide (CO2) for enhanced oil recovery, depending on the CO2 distribution within the fracture network and distance between fractures. High oil recovery was observed during miscible, supercritical CO2 injection (RF = 86% original oil in place) in the laboratory with a fractured chalk core plug with a large permeability contrast. Dynamic 3D fluid saturations from computed-tomography (CT) imaging made it possible to study the local oil displacement in the vicinity of the fracture, and to calculate an effective diffusion coefficient with analytical methods. The obtained diffusion coefficient varies between 0.83 and 1.2 ×10−9m2/s, depending on the method used for calculation. A numerical sensitivity analysis, with a validated numerical model that reproduced the experiments, showed that the rate of oil production during CO2 injection declined exponentially with increasing diffusion lengths from the CO2-filled fracture and oil-filled matrix. In a numerical upscaling effort, with the experimentally achieved diffusion coefficient, oil-recovery rates and local flow were studied in an inverted five-spot pattern in a heavily fractured carbonate reservoir.

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Journal articles on the topic 'Oil flow visualization'

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