Relevant bibliographies by topics / Oil and gas flow

Contents

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

Academic literature on the topic 'Oil and gas flow'

Author: Grafiati
Published: 4 June 2021
Last updated: 18 February 2022

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Journal articles on the topic "Oil and gas flow"

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Mlkvik, Marek, Róbert Olšiak, and Marek Smolar. "Comparison of the Viscous Liquids Spraying by the OIG and the Oil Configurations of an Effervescent Atomizer at Low Inlet Pressures." Strojnícky casopis – Journal of Mechanical Engineering 66, no. 1 (July 1, 2016): 53–64. http://dx.doi.org/10.1515/scjme-2016-0011.

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AbstractIn this work we studied the influence of the fluid injection configuration (OIG: outside-in-gas, OIL: outside-in-liquid) on the internal flows and external sprays parameters. We sprayed the viscous aqueous maltodextrin solutions (μ = 60 mPa·s) at a constant inlet pressure of the gas and the gas to the liquid mass flow ratio (GLR) within the range 2.5 to 20%. We found that the fluids injection has a crucial influence on the internal flows. The internal flows patterns for the OIG atomizer were the slug flows, the internal flow of the OIL device was annular which led to the significant improvement of the spray quality: Smaller droplets, faster atomization, fewer pulsations.
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Li, Yingwei, Jing Gao, Xingbin Liu, and Ronghua Xie. "Energy Demodulation Algorithm for Flow Velocity Measurement of Oil-Gas-Water Three-Phase Flow." Mathematical Problems in Engineering 2014 (2014): 1–13. http://dx.doi.org/10.1155/2014/705323.

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Flow velocity measurement was an important research of oil-gas-water three-phase flow parameter measurements. In order to satisfy the increasing demands for flow detection technology, the paper presented a gas-liquid phase flow velocity measurement method which was based on energy demodulation algorithm combing with time delay estimation technology. First, a gas-liquid phase separation method of oil-gas-water three-phase flow based on energy demodulation algorithm and blind signal separation technology was proposed. The separation of oil-gas-water three-phase signals which were sampled by conductance sensor performed well, so the gas-phase signal and the liquid-phase signal were obtained. Second, we used the time delay estimation technology to get the delay time of gas-phase signals and liquid-phase signals, respectively, and the gas-phase velocity and the liquid-phase velocity were derived. At last, the experiment was performed at oil-gas-water three-phase flow loop, and the results indicated that the measurement errors met the need of velocity measurement. So it provided a feasible method for gas-liquid phase velocity measurement of the oil-gas-water three-phase flow.
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Bonilla Riaño, Adriana, Antonio Carlos Bannwart, and Oscar M. H. Rodriguez. "Film thickness planar sensor in oil-water flow: prospective study." Sensor Review 35, no. 2 (March 16, 2015): 200–209. http://dx.doi.org/10.1108/sr-09-2014-702.

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Purpose – The purpose of this paper is to study a multiphase-flow instrumentation for film thickness measurement, especially impedance-based, not only for gas–liquid flow but also for mixtures of immiscible and more viscous substances such as oil and water. Conductance and capacitive planar sensors were compared to select the most suitable option for oil – water dispersed flow. Design/methodology/approach – A study of techniques for measurement of film thickness in oil – water pipe flow is presented. In the first part, some measurement techniques used for the investigation of multiphase flows are described, with their advantages and disadvantages. Next, examinations of conductive and capacitive techniques with planar sensors are presented. Findings – Film thickness measurement techniques for oil–water flow are scanty in the literature. Some techniques have been used in studies of annular flow (gas–liquid and liquid–liquid flows), but applications in other flow patterns were not encountered. The methods based on conductive or capacitive measurements and planar sensor are promising solutions for measuring time-averaged film thicknesses in oil–water flows. A capacitive system may be more appropriate for oil–water flows. Originality/value – This paper provides a review of film thickness measurements in pipes. There are many reviews on gas – liquid flow measurement but not many about liquid – liquid flow.
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Wang, Hai Qin, Lei Zhang, Yong Wang, and De Xuan Li. "The Effects of Low Flow Rate Gas Involvement on Oil-Water Flow in Horizontal Pipes." Advanced Materials Research 354-355 (October 2011): 41–44. http://dx.doi.org/10.4028/www.scientific.net/amr.354-355.41.

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The experiments were conducted in a horizontal multiphase flow test loop (50mm inner diameter, 40m long) to investigate the flow of oil/water and the influence of an involved gas phase with low flow rate in horizontal pipes, specifically including oil/water flow patterns, cross-section water holdup and pipe flow pressure gradient. The experimental results indicated that the involved gas with low flow rate had a considerable effect on oil/water flow characteristics, which shows the complexity of gas/oil/water three-phase flow. Thus, this effect could not be ignored in design and operation management of oil/gas gathering and transportation system.
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Samuel, Revelation J., and Haroun Mahgerefteh. "Transient Flow Modelling of Start-up CO2 Injection into Highly-Depleted Oil/Gas Fields." International Journal of Chemical Engineering and Applications 8, no. 5 (October 2017): 319–26. http://dx.doi.org/10.18178/ijcea.2017.8.5.677.

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Hoffman, Monty, and James Crafton. "Multiphase flow in oil and gas reservoirs." Mountain Geologist 54, no. 1 (January 2017): 5–14. http://dx.doi.org/10.31582/rmag.mg.54.1.5.

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The porous rocks that make up oil and gas reservoirs are composed of complex combinations of pores, pore throats, and fractures. Pore networks are groups of these void spaces that are connected by pathways that have the same fluid entry pressures. Any fluid movement in pore networks will be along the pathways that require the minimum energy expenditure. After emplacement of hydrocarbons in a reservoir, fluid saturations, capillary pressure, and energy are in equilibrium, a significant amount of the reservoir energy is stored at the interface between the fluids. Any mechanism that changes the pressure, volume, chemistry, or temperature of the fluids in the reservoir results in a state of energy non-equilibrium. Existing reservoir engineering equations do not address this non-equilibrium condition, but rather assume that all reservoirs are in equilibrium. The assumption of equilibrium results in incorrect descriptions of fluid flow in energy non-equilibrium reservoirs. This, coupled with the fact that drilling-induced permeability damage is common in these reservoirs, often results in incorrect conclusions regarding the potential producibility of the well. Relative permeability damage, damage that can change which fluids are produced from a hydrocarbon reservoir, can occur even in very permeable reservoirs. Use of dependent variables in reservoir analysis does not correctly describe the physics of fluid flow in the reservoir and will lead to potentially incorrect answers regarding producibility of the reservoir.
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Tang, Guo-Qing, Yi Tak Leung, Louis M. Castanier, Akshay Sahni, Frederic Gadelle, Mridul Kumar, and Anthony R. Kovscek. "An Investigation of the Effect of Oil Composition on Heavy Oil Solution-Gas Drive." SPE Journal 11, no. 01 (March 1, 2006): 58–70. http://dx.doi.org/10.2118/84197-pa.

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Summary This study probes experimentally the mechanisms of heavy-oil solution gas drive through a series of depletion experiments employing two heavy crude oils and two viscous mineral oils. Mineral oils were chosen with viscosity similar to crude oil at reservoir temperature. A specially designed aluminum coreholder allows visualization of gas phase evolution during depletion using X-ray computed tomography (CT). In addition, a visualization cell was installed at the outlet of the sandpack to monitor the flowing-gas-bubble behavior vs. pressure. Bubble behavior observed at the outlet corroborates CT measurements of in-situ gas saturation vs. pressure. Both depletion rate and oil composition affect the size of mobile bubbles. At a high depletion rate (0.035 PV/hr), a foam-like flow of relatively small pore-sized bubbles dominates the gas and oil production of both crude oils. Conversely, at a low depletion rate (0.0030 PV/hr), foam-like flow is not observed in the less viscous crude oil; however, foam-like flow behavior is still found for the more viscous crude oil. No foam-like flow is observed for the mineral oils. In-situ imaging shows that the gas saturation distribution along the sandpack is not uniform. As the pattern of produced gas switches from dispersed bubbles to free gas flow, the distribution of gas saturation becomes even more heterogeneous. This indicates that a combination of pore restrictions and gravity forces significantly affects free gas flow. Additionally, results show that solution-gas drive is effective even at reservoir temperatures as great as 80°C. Oil recovery ranges from 12 to 30% OOIP; the higher the depletion rate, the greater the recovery rate. Introduction Solution gas drive has shown unexpectedly high recovery efficiency in some heavy-oil reservoirs. The mechanisms, however, that have been proposed are speculative, sometimes contradictory, and do not explain fully the origin of high primary oil recovery and slow decline in reservoir pressure. Smith (1988) first identified this effect. He hypothesized that gas bubbles smaller than pore constrictions are liberated from the oil, but are not able to form a continuous gas phase and flow freely. Instead, the gas bubbles exist in a dispersed state in the oil and only flow with the oil phase. Smith stated that oil viscosity is reduced significantly, resulting in high recovery performance. Later, many researchers focused on so-called foamy-oil behavior. Claridge and Prats (1995) hypothesized that heavy-oil components (such as asphaltenes) concentrate at the interfaces between oil and gas bubbles, thereby preventing bubbles from coalescing into a continuous gas phase. Bubbles are assumed to be smaller than pore dimensions. Claridge and Prats stated that the concentration of heavy-oil components at the interfaces results in a reduction of the viscosity of the remaining oil. Bora et al. (2000) discussed the flow behavior of solution gas drive in heavy oils. Based on their studies, they found that dispersed gas bubbles do not coalesce rapidly in heavy oil, especially at high depletion rate. They stated that the main feature of the gas/oil dispersion is a reduced viscosity compared to the original oil. Models to explain the experimental results were also established (Sheng et al. 1994, 1996, 1999, 1995).
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Bannwart, Antonio C., Oscar M. H. Rodriguez, Carlos H. M. de Carvalho, Isabela S. Wang, and Rosa M. O. Vara. "Flow Patterns in Heavy Crude Oil-Water Flow." Journal of Energy Resources Technology 126, no. 3 (September 1, 2004): 184–89. http://dx.doi.org/10.1115/1.1789520.

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This paper is aimed to an experimental study on the flow patterns formed by heavy crude oil (initial viscosity and density 488 mPa s, 925.5kg/m3 at 20°C) and water inside vertical and horizontal 2.84-cm-i.d. pipes. The oil-water interfacial tension was 29 dyn/cm. Effort is concentrated into flow pattern characterization, which was visually defined. The similarities with gas-liquid flow patterns are explored and the results are expressed in flow maps. In contrast with other studies, the annular flow pattern (“core annular flow”) was observed in both horizontal and vertical test sections. These flow pattern tends to occur in heavy oil-water flows at low water input fractions. Because of the practical importance of core flow in providing an effective means for heavy oil production and transportation, this paper discusses criteria that favor its occurrence in pipes.
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Xin, D., J. Feng, X. Jia, and X. Peng. "An investigation into oil—gas two-phase leakage flow through micro gaps in oil-injected compressors." Proceedings of the Institution of Mechanical Engineers, Part C: Journal of Mechanical Engineering Science 224, no. 4 (April 1, 2010): 925–33. http://dx.doi.org/10.1243/09544062jmes1704.

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This article presents the investigation on the oil—gas two-phase leakage flow through the micro gaps in oil-injected compressors and provides a new way of investigating the internal leakage process in the compressors. The oil—gas leakage rates were measured through the micro gaps of various gap sizes, the volume ratios of oil to gas, and pressure differences/ratios; and the flow patterns reflecting the flow characteristics were observed by using a high-speed video. The experimental results showed that the leakage flowrate was significantly related to the flow patterns in the gap, which were similar to those found in the existing literature and agreed well with the predicted ones by the Weber number. The gas leakage flowrate through the gap increased rapidly with the increased pressure ratio until the pressure ratio reached the critical pressure ratio, which ranged from 1.8 to 2.7. At the critical pressure ratio, the flow pattern transition from churn flow to annular flow occurred, resulting in gas leakage driven by a different sealing mechanism. As the volume ratio of oil to gas increased by 0.5 per cent, the gas leakage flowrate decreased by 77 per cent.
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Carcaño-Silvan, C. A., G. Soto-Cortes, and F. Rivera-Trejo. "Characterization of slug flow in heavy oil and gas mixtures." Revista Mexicana de Ingeniería Química 20, no. 1 (March 26, 2020): 1–12. http://dx.doi.org/10.24275/rmiq/proc1289.

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Dissertations / Theses on the topic "Oil and gas flow"

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Valle, Arne. "Three phase gas-oil-water pipe flow." Thesis, Imperial College London, 2000. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.248608.

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Odozi, Utomi Ayodele. "Three-phase gas/liquid/liquid slug flow." Thesis, Imperial College London, 2000. http://hdl.handle.net/10044/1/8444.

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Santos, Pedro Miguel Matos dos. "Investment in new HUB for Oil & Gas Engineering Centres by Oil & Gas Services Companies." Master's thesis, Instituto Superior de Economia e Gestão, 2014. http://hdl.handle.net/10400.5/7882.

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Mestrado em Finanças
O renovado interesse na indústria petrolífera coloca-a no topo da lista de prioridades de investimento estrangeiro para alguns países. A competitividade empresarial é um factor bastante importante numa Sociedade global e, como tal, um factor que não pode ser descurado a este nível. O objectivo deste trabalho assenta no estudo de uma decisão de investimento referente à possível expansão da actividade de empresas prestadoras de serviços na indústria petrolífera. Além da definição do enunciado da situação, uma resolução é apresentada. Esta resolução assenta em três metodologias distintas: - Modelo Free Cash-Flow; - Análise Strengths, Weaknesses, Opportunities e Threats (SWOT); - Modelo Matriz Híbrida. O modelo de Free Cash-Flow permitiu considerar os custos de capital de cada empresa e chegar a uma conclusão sobre o país/local que apresenta as métricas financeiras mais apelativas. A análise SWOT oferece-nos uma visão mais generalista acerca dos países considerados sobre a perspectiva de investimento.. Com o intuito de analisar factores estratégicos induzidos por parâmetros externos (de forma a não considerar apenas métricas financeiras), foi criada uma Matriz Híbrida e foi realizada a respectiva análise. Neste seguimento, os resultados apresentados pelo Modelo de Matriz Híbrida deverão ser considerados aquando da decisão de expansão. Foi possível concluir que a melhor opção base é a criação de um escritório em Portugal. Apesar desta conclusão, a solução óptima é observada quando contabilizamos os custos de abrir um escritório em Portugal e quando, simultaneamente, consideramos os impostos que são pagos na Holanda (devido à sua política de impostos mais atractiva).
The renewed interest in the Oil & Gas sector places this Industry at the top of the list of priorities for some countries in order to attract foreign investment. Corporate competitiveness is, therefore, an extremely important vehicle for a globalized Society. The aim of the present work was to study the possible investment contemplated by an expansion decision taken by some Oil & Gas Services companies. Besides the definition of the problem, an adequate resolution is also presented. This resolution is sustained by three distinct methodologies: - Free Cash-Flow Model; - Strengths, Weaknesses, Opportunities and Threats (SWOT) analysis; - Hybrid Matrix Model. The Free Cash-Flow Model enabled us to consider costs of capital and come to a decision regarding the country that presented the best financial results. The SWOT analysis provided a more generalist view over the several analysed countries. With the purpose of analysing strategic factors induced by external parameters (besides the financial field), the Hybrid Matrix Model was created and a study was carried out. Subsequently, the results presented by the Hybrid Matrix Model shall be taken into account when choosing a location for an international expansion. It was possible to conclude that the best base scenario is observed when opening an Office in Portugal. However, the optimal solution would be opening an Office in Portugal and account the profits/losses in the Netherlands, mixing the country that presents the lowest costs with the country that has the best taxation policies.
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Camacho-Velázquez, Rodolfo Gabriel. "Well performance under solution gas drive /." Access abstract and link to full text, 1987. http://0-wwwlib.umi.com.library.utulsa.edu/dissertations/fullcit/8720613.

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Abdulkareem, Lokman Aziz. "Tomographic investigation of gas-oil flow in inclined risers." Thesis, University of Nottingham, 2011. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.546555.

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Darman, Nasir B. Haji. "Upscaling of two-phase flow in oil-gas systems." Thesis, Heriot-Watt University, 2000. http://hdl.handle.net/10399/570.

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Labed, Ismail. "Gas-condensate flow modelling for shale gas reservoirs." Thesis, Robert Gordon University, 2016. http://hdl.handle.net/10059/2144.

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In the last decade, shale reservoirs emerged as one of the fast growing hydrocarbon resources in the world unlocking vast reserves and reshaping the landscape of the oil and gas global market. Gas-condensate reservoirs represent an important part of these resources. The key feature of these reservoirs is the condensate banking which reduces significantly the well deliverability when the condensate forms in the reservoir below the dew point pressure. Although the condensate banking is a well-known problem in conventional reservoirs, the very low permeability of shale matrix and unavailability of proven pressure maintenance techniques make it more challenging in shale reservoirs. The nanoscale range of the pore size in the shale matrix affects the gas flow which deviates from laminar Darcy flow to Knudsen flow resulting in enhanced gas permeability. Furthermore, the phase behaviour of gas-condensate fluids is affected by the high capillary pressure in the matrix causing higher condensate saturation than in bulk conditions. A good understanding and an accurate evaluation of how the condensate builds up in the reservoir and how it affects the gas flow is very important to manage successfully the development of these high-cost hydrocarbon resources. This work investigates the gas Knudsen flow under condensate saturation effect and phase behaviour deviation under capillary pressure of gas-condensate fluids in shale matrix with pore size distribution; and evaluates their effect on well productivity. Supplementary MATLAB codes are provided elsewhere on OpenAIR: http://hdl.handle.net/10059/2145.
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Tay, Boon Li. "Forces on pipe bends due to intermittent gas-liquid flow." Thesis, University of Cambridge, 2002. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.289501.

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Kee, Kok Eng. "A Study of Flow Patterns and Surface Wetting in Gas-Oil-Water Flow." Ohio University / OhioLINK, 2014. http://rave.ohiolink.edu/etdc/view?acc_num=ohiou1401985339.

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Mohammadi, Shahrokh. "Stochastic modelling of capillary dominated gas condensate flow in porousmedia." Thesis, Heriot-Watt University, 1993. http://hdl.handle.net/10399/1451.

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Books on the topic "Oil and gas flow"

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Sun, Baojiang. Multiphase Flow in Oil and Gas Well Drilling. Singapore: John Wiley & Sons Singapore Pte. Ltd, 2016. http://dx.doi.org/10.1002/9781118720288.

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Gudmundsson, Jon Steinar. Flow Assurance Solids in Oil and Gas Production. London, UK : CRC Press/Balkema, [2017]: CRC Press, 2017. http://dx.doi.org/10.1201/9781315185118.

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O, Thomsen René, ed. Hydrodynamics of oil and gas. New York: Plenum Press, 1994.

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Li, Dang, and Junbin Chen. Mechanics of Oil and Gas Flow in Porous Media. Singapore: Springer Singapore, 2021. http://dx.doi.org/10.1007/978-981-15-7313-2.

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Gao, Zhong-Ke, Ning-De Jin, and Wen-Xu Wang. Nonlinear Analysis of Gas-Water/Oil-Water Two-Phase Flow in Complex Networks. Berlin, Heidelberg: Springer Berlin Heidelberg, 2014. http://dx.doi.org/10.1007/978-3-642-38373-1.

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Bertrand, Marianne. Profitable investments or dissipated cash?: Evidence on the investment-cash flow relationship from oil and gas lease bidding. Cambridge, MA: National Bureau of Economic Research, 2005.

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Hwang, du-Hyun Dwayne. Flow quality measurement based on stratification of flow in nitrogen gas-water and HFC-134a refrigerant-PAG oil two-phase flow systems. Ottawa: National Library of Canada, 2001.

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Hayes, D. G. Tomographic flow measurement by combining component distribution and velocity profile measurements in 2-phase oil/gas flows. Manchester: UMIST, 1994.

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Rathmann, Ole. Multwo: Compositional computer model for transient oil/gas two-phase flow : The EFP-85 Project. Roskilde: Dept. of Energy Technology/Section of Heat Transfer and Hydraulics Riso National Laboratory, 1986.

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International, Conference on Multi-Phase Production (8th 1997 Cannes France). 8th International Conference on Multiphase '97: How deep? how far? how soon? Bury St Edmunds, Suffolk, U.K: Mechanical Engineering Publications, 1997.

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Book chapters on the topic "Oil and gas flow"

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Lerche, Ian, and René O. Thomsen. "Dynamical Aspects of Permeable Flow." In Hydrodynamics of Oil and Gas, 169–77. Boston, MA: Springer US, 1994. http://dx.doi.org/10.1007/978-1-4899-1301-2_10.

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Gudmundsson, Jon Steinar. "Flow phenomena." In Flow Assurance Solids in Oil and Gas Production, 15–44. London, UK : CRC Press/Balkema, [2017]: CRC Press, 2017. http://dx.doi.org/10.1201/9781315185118-2.

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Gudmundsson, Jon Steinar. "Natural gas hydrate." In Flow Assurance Solids in Oil and Gas Production, 129–57. London, UK : CRC Press/Balkema, [2017]: CRC Press, 2017. http://dx.doi.org/10.1201/9781315185118-5.

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ANDERSON, TED L. "Flaw Assessment." In Oil and Gas Pipelines, 579–86. Hoboken, New Jersey: John Wiley & Sons, Inc., 2015. http://dx.doi.org/10.1002/9781119019213.ch40.

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Bagirov, E., and I. Lerche. "Mud Flow Hazards." In Impact of Natural Hazards on Oil and Gas Extraction, 123–47. Boston, MA: Springer US, 1999. http://dx.doi.org/10.1007/978-1-4757-3019-7_5.

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Li, Dang, and Junbin Chen. "Percolation Theory of Oil-Gas Two Phases (Dissolved Gas Drive)." In Mechanics of Oil and Gas Flow in Porous Media, 239–59. Singapore: Springer Singapore, 2020. http://dx.doi.org/10.1007/978-981-15-7313-2_7.

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King, P. R. "Rescaling of Flow Parameters Using Renormalization." In North Sea Oil and Gas Reservoirs — III, 265–71. Dordrecht: Springer Netherlands, 1994. http://dx.doi.org/10.1007/978-94-011-0896-6_22.

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Degouy, D., and J. Lecourtier. "A Flow Loop to Test Drilling Fluids under Bottomhole Conditions." In The European Oil and Gas Conference, 401–2. Dordrecht: Springer Netherlands, 1991. http://dx.doi.org/10.1007/978-94-010-9844-1_55.

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Li, Dang, and Junbin Chen. "Percolation Law of Natural Gas." In Mechanics of Oil and Gas Flow in Porous Media, 163–82. Singapore: Springer Singapore, 2020. http://dx.doi.org/10.1007/978-981-15-7313-2_5.

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Bedrikovetsky, Pavel, and Gren Rowan. "Percolation Models of Flow through a Porous Medium." In Mathematical Theory of Oil and Gas Recovery, 27–39. Dordrecht: Springer Netherlands, 1993. http://dx.doi.org/10.1007/978-94-017-2205-6_2.

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Conference papers on the topic "Oil and gas flow"

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SADRI, MAHDI, SEYED SHARIATIPOUR, and ANDREW HUNT. "EFFECTS OF FLOW MEASUREMENT ERRORS ON OIL AND GAS PRODUCTION FORECASTS." In MULTIPHASE FLOW 2017. Southampton UK: WIT Press, 2017. http://dx.doi.org/10.2495/mpf170141.

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Mohammed, Nuhu, Abbas Jibrin Abubakar, Godpower Chimagwu Enyi, and Ghasem Nasr Ghavami. "Flow Characteristics Through Gas Alternating Gas Injection During Enhanced Gas Recovery." In SPE Gas & Oil Technology Showcase and Conference. Society of Petroleum Engineers, 2019. http://dx.doi.org/10.2118/198658-ms.

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Bedrikovetsky, Pavel G. "Suspension Flow in Petroleum Reservoirs: Fractional Flow Theory." In Asia Pacific Oil and Gas Conference and Exhibition. Society of Petroleum Engineers, 2007. http://dx.doi.org/10.2118/110929-ms.

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Al-Hashimy, Z. I., H. H. Al-Kayiem, Z. K. Kadhim, and A. O. Mohmmed. "Numerical simulation and pressure drop prediction of slug flow in oil/gas pipelines." In MULTIPHASE FLOW 2015. Southampton, UK: WIT Press, 2015. http://dx.doi.org/10.2495/mpf150051.

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Basquet, Remy, Jeannin Laurent, Arnaud Lange, Bernard Bourbiaux, and Sylvain Sarda. "Gas Flow Simulation in Discrete Fracture Network Models." In Middle East Oil Show. Society of Petroleum Engineers, 2003. http://dx.doi.org/10.2118/81513-ms.

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Izadi Kamouei, Mehdi, and Turhan Yildiz. "Transient Flow in Discretely Fractured Porous Media." In Rocky Mountain Oil & Gas Technology Symposium. Society of Petroleum Engineers, 2007. http://dx.doi.org/10.2118/108190-ms.

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Borovkov, A. I., I. B. Voynov, Y. B. Galerkin, A. F. Rekstin, and A. A. Drozdov. "Supersonic centrifugal compressor flow part optimization experience." In OIL AND GAS ENGINEERING (OGE-2018). Author(s), 2018. http://dx.doi.org/10.1063/1.5051912.

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Zhang, Yihe, and Liming Dai. "A Comparison of Oil-Water Flow and Oil-Gas Flow in Capillary Model." In ASME 2012 International Mechanical Engineering Congress and Exposition. American Society of Mechanical Engineers, 2012. http://dx.doi.org/10.1115/imece2012-87720.

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Abstract:
A capillary model is employed to study the slug flow behavior in pore structure. Oil-water system and oil-gas system are investigated in the experiments. During the flow process, it is observed that the wetting phase liquid will generate a thin liquid film on the inner surface of the tube wall, and the liquid film plays an important role in capillary flow. At the meantime, the pressure drop across the tube is recorded during the experiment, result shows that the pressure drop magnitude is proportional to the oil slug length, while it is not significantly affected by the liquid injecting velocity.
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Moradi, B., M. Hossain, and G. Oluyemi. "Mechanistic model for four-phase sand/water/oil/gas stratified flow in horizontal pipes." In MULTIPHASE FLOW 2015. Southampton, UK: WIT Press, 2015. http://dx.doi.org/10.2495/mpf150291.

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10

Ettehadi Osgouei, Reza, Mehmet Evren Ozbayoglu, Murat Ahmet Ozbayoglu, and Ertan Yuksel. "Flow Pattern Identification Of Gas-Liquid Flow Through Horizontal Annular Geometries." In SPE Oil and Gas India Conference and Exhibition. Society of Petroleum Engineers, 2010. http://dx.doi.org/10.2118/129123-ms.

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Reports on the topic "Oil and gas flow"

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Stormont, John C., Mahmoud Reda Taha, Ishtiaque Anwar, Mahya Hatabeigi, Kirsten N. Chojnicki, and Giorgia Bettin. Oil and gas flow through fractures and along interfaces in well cement. Office of Scientific and Technical Information (OSTI), March 2018. http://dx.doi.org/10.2172/1489868.

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Bertrand, Marianne, and Sendhil Mullainathan. Profitable Investments or Dissipated Cash? Evidence on the Investment-Cash Flow Relationship From Oil and Gas Lease Bidding. Cambridge, MA: National Bureau of Economic Research, February 2005. http://dx.doi.org/10.3386/w11126.

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Morrell, G. R. Oil and gas discoveries. Natural Resources Canada/ESS/Scientific and Technical Publishing Services, 1996. http://dx.doi.org/10.4095/207707.

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Shrouf, R. G., and S. R. Page. Gas flow characterization of restrictive flow orifice devices. Office of Scientific and Technical Information (OSTI), July 1997. http://dx.doi.org/10.2172/510304.

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Sheng, James, Lei Li, Yang Yu, Xingbang Meng, Sharanya Sharma, Siyuan Huang, Ziqi Shen, et al. Maximize Liquid Oil Production from Shale Oil and Gas Condensate Reservoirs by Cyclic Gas Injection. Office of Scientific and Technical Information (OSTI), November 2017. http://dx.doi.org/10.2172/1427584.

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Joseph Rovani and John Schabron. Enhanced Oil Recovery: Aqueous Flow Tracer Measurement. Office of Scientific and Technical Information (OSTI), February 2009. http://dx.doi.org/10.2172/993825.

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Thomas J. Hanratty. Gas-Liquid Flow in Pipelines. Office of Scientific and Technical Information (OSTI), February 2005. http://dx.doi.org/10.2172/837116.

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Skone, Timothy J. Oilfield Gas, Water, and Oil Separation. Office of Scientific and Technical Information (OSTI), October 2012. http://dx.doi.org/10.2172/1509428.

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International Oil and Gas Market Outlook. Chair Shahd Alrashed and Colin Ward. King Abdullah Petroleum Studies and Research Center, December 2018. http://dx.doi.org/10.30573/ks--2018-wb22.

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Manne, A. D. Attic oil recovery by gas injection. Office of Scientific and Technical Information (OSTI), December 1994. http://dx.doi.org/10.2172/661377.

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