Relevant bibliographies by topics / Oil wells

Academic literature on the topic 'Oil wells'

Author: Grafiati
Published: 4 June 2021
Last updated: 1 August 2024

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Journal articles on the topic "Oil wells"

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ON, Shemelina. "Constructing a Heavy Oil Well." Petroleum & Petrochemical Engineering Journal 6, no. 1 (2022): 1–6. http://dx.doi.org/10.23880/ppej-16000300.

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The article presents a description of the designs of wells intended for the production of high-viscosity oil. The main problems associated with the planning and deployments of architecture, construction of high-viscosity oil wells are described. World experience in well construction is presented. Vertical wells are usually used for primary cold production and cyclic steam or steam flooding processes. On the other hand, increased reservoir contact may require deviated, horizontal, or multilateral wells. In the case of steam-assisted gravity drainage (SAGD) and some solvent injection processes, the recovery process may require a well-placed pair of horizontal wells. Advanced drilling and real-time measurement technologies reviewed. Geo mechanical factors are studied when considering the implementation of any steam or thermal processes in the field. Examples of construction of multilateral wells in various combinations are shown depending on the field development strategy and for maximum reservoir drainage. The main recommendations for the placement of wells are proposed.
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S, Gomaa. "Electrical Submersible Pump Design in Vertical Oil Wells." Petroleum & Petrochemical Engineering Journal 4, no. 4 (2020): 1–7. http://dx.doi.org/10.23880/ppej-16000237.

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Artificial Lift is a very essential tool to increase the oil production rate or lift the oil column in the wellbore up to the surface. Artificial lift is the key in case of bottom hole pressure is not sufficient to produce oil from the reservoir to the surface. So, a complete study is carried to select the suitable type of artificial lift according to the reservoir and wellbore conditions like water production, sand production, solution gas-oil ratio, and surface area available at the surface. Besides, the maintenance cost and volume of produced oil have an essential part in the selection of the type of artificial lift tool. Artificial lift tools have several types such as Sucker Rod Pump, Gas Lift, Hydraulic Pump, Progressive Cavity Pump, Jet Pump, and Electrical Submersible Pump. All these types require specific conditions for subsurface and surface parameters to apply in oil wells. This paper will study the Electrical Submersible Pump “ESP” which is considered one of the most familiar types of artificial lifts in the whole world. Electrical Submersible Pump “ESP” is the most widely used for huge oil volumes. In contrast, ESP has high maintenance and workover cost. Finally, this paper will discuss a case study for the Electrical Submersible pump “ESP” design in an oil well. This case study includes the entire well and reservoir properties involving fluid properties to be applied using Prosper software. The results of the design model will impact oil productivity and future performance of oil well.
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Sarsenbaevna, Batirova Uldaykhan, Tajetdinova Gulnora Abatbay qizi, and Karjaubayev Marat Ospanovich. "THE PROCESS OF DRILLING OIL AND GAS WELLS." American Journal of Applied Sciences 6, no. 6 (June 1, 2024): 49–52. http://dx.doi.org/10.37547/tajas/volume06issue06-08.

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The process of drilling oil and gas wells is a critical component of the energy industry, playing an important role in the extraction of vital natural resources. This article provides an in-depth exploration of the intricate procedures and technologies involved in drilling operations. From initial site preparation to the complexities of directional drilling, this article aims to shed light on the multifaceted process of extracting oil and gas from beneath the Earth's surface. Throughout this exploration, we will delve into the fundamental principles, safety considerations, environmental impacts, and innovative advancements that shape the modern landscape of drilling operations.
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Carpenter, Chris. "Expertise in Complex-Well Construction Leveraged for Geothermal Wells." Journal of Petroleum Technology 75, no. 05 (May 1, 2023): 87–89. http://dx.doi.org/10.2118/0523-0087-jpt.

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_ This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 204097, “Constructing Deep Closed-Loop Geothermal Wells for Globally Scalable Energy Production by Leveraging Oil and Gas Extended-Reach Drilling and High-Pressure/High-Temperature Well-Construction Expertise,” by Eric van Oort, SPE, Dongmei Chen, SPE, and Pradeepkumar Ashok, SPE, The University of Texas at Austin, et al. The paper has not been peer reviewed. _ In the complete paper, deep closed-loop geothermal systems (DCLGS) are introduced as an alternative to traditional enhanced geothermal systems (EGS) for green energy production that is globally scalable and dispatchable. The authors demonstrate that DCLGS wells can generate power on a scale comparable to that of EGS. They also highlight technology gaps and needs that still exist for economically drilling DCLGS wells, writing that it is possible to extend oil and gas technology, expertise, and experience in extended-reach drilling (ERD) and high-pressure/high-temperature (HP/HT) drilling to construct complex DCLGS wells. Introduction CLGS is considered a subset of EGS, but the authors write that it is a distinct entity. EGS mostly involves well designs that rely on fractures for heat extraction. Such systems are different from CLGS wells in that the latter use closed conduits for thermal fluid circulation and heating. CLGS relies on fluids pumped through a closed loop. The authors treat CLGS systems as being different from EGS systems, with the understanding that drilling technologies discussed in the paper as enablers for CLGS wells apply equally to EGS wells. In the geothermal (GT) domain, the majority of attention and funding currently is assigned to EGS projects. A case is made in the complete paper to continue to develop DCLGS technology because of its favorable risk profile compared with EGS. Part I of the complete paper introduces a hydraulic model coupled with a thermal model suitable for calculating the power generation of DCLGS wells. This synopsis concentrates instead on Part II of the complete paper, in which technology gaps and needs of DCLGS drilling and well construction are highlighted and opportunities identified where oil and gas experience and technology can be directly applied and leveraged. Similarities and Differences of Deep GT and Oil and Gas HP/HT Wells - GT wells generally use larger production hole sizes than typical land wells. - Casing-cement annuli typically are cemented back to surface. - GT wells can be drilled in more-forgiving pore-pressure fracture gradient (PPFG) environments with wider drilling margins than geopressured HP/HT wells in hydrocarbon systems. - Severe lost circulation appears to be a universal problem in deep GT wells. - Drilling costs can account for 50% or more of the total capital costs for a GT energy project. - Data sets on GT wells are much smaller than those for oil and gas wells.
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Liashenko, Anna, Valeriy Makarenko, Yuriy Vynnykov, and Oleksandr Petrash. "Oil wells hydrate formation regularities." Eastern-European Journal of Enterprise Technologies 3, no. 6 (111) (June 18, 2021): 19–24. http://dx.doi.org/10.15587/1729-4061.2021.233511.

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The paper considers the process of hydrate-paraffin deposits formation in oil wells. Due to the research with the author's specially designed laboratory equipment – an experimental installation containing a technological unit and an information-measuring system, the most favorable pressure-temperature conditions of hydrate formation in a wide range of pressure (0.1–120 MPa) and temperature (from –20 to +80 °C) were determined. The experimental results made it possible to determine the conditions required for hydrate deposits and iron (Fe) oxides in the range of temperature from –15 to +60 °C and pressure from 0 to 60 MPa. These results are confirmed by thermodynamic calculations of the oil-gas-hydrate phase equilibria in the annulus of the well. Data processing was performed using the methods of correlation, dispersion and regression analysis, which allowed comparing the processes of hydrates and iron (Fe) oxides formation in the annulus of oil wells. The results of the study can be used to prevent and eliminate hydrate-paraffin plugs in the downhole equipment of oil wells, and also to determine the operation mode of the well for long-term operation of the downhole equipment without complications, accidents and stops for repair works, which reduces downtime.
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Rassoul, G. A. R., and Omar M. Waheeb. "Producing Oil from Dead Oil Wells Using injected LPG." Iraqi Journal of Chemical and Petroleum Engineering 11, no. 2 (June 30, 2010): 29–33. http://dx.doi.org/10.31699/ijcpe.2010.2.3.

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In order to reduce hydrostatic pressure in oil wells and produce oil from dead oil wells, laboratory rig was constructed, by injecting LPG through pipe containing mixture of two to one part of East Baghdad crude oil and water. The used pressure of injection was 2.0 bar, which results the hydrostatic pressure reduction around 246 to 222 mbar and flow rate of 34.5 liter/hr fluid (oil-water), at 220 cm injection depth. Effects of other operating parameters were also studied on the behavior of two phase flow and on the production of oil from dead oil wells.
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Alsheikhly, M. J., and Sh J. Mirboboev. "FEATURES OF WELL TEST INTERPRETATION RESULTS IN HORIZONTAL WELLS." Oil and Gas Studies, no. 2 (May 1, 2018): 32–34. http://dx.doi.org/10.31660/0445-0108-2018-2-32-34.

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The article explores the features of well test interpretation results of oil and gas horizontal wells in the southern Iraqi fields. The author pays attention to the deconvolution method during processing the results of studying horizontal wells. The conclusion is made to determine the boun-daries of the drainage area of the wells on the need for a long-term study of horizontal wells.
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Li, Guang Fu. "Low-Yielding Wells Automatic Metering System." Advanced Materials Research 953-954 (June 2014): 1467–70. http://dx.doi.org/10.4028/www.scientific.net/amr.953-954.1467.

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When oil field entered into the high water content period, liquid production capacity of oil wells had large fluctuation and poor regularity, which leaded to the error of human reading and bottom water density in the measurement process, the difficulty of measuring oil wells is gradually increasing. Therefore, the measurement of low producing well has aroused extensive attention. How to research and establish a suitable measuring device for low producing well, improve measurement accuracy and management level of intermittent oil wells has become a serious problem in oil production. Using automatic oil measuring system can improve the accuracy of measurement, which achieved the automatic measurement for the fluid and gas production and moisture content of oil wells.
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Blick, E. F., P. N. Enga, and P. C. Lin. "Stability Analysis of Flowing Oil Wells and Gas Lift Wells." SPE Production Engineering 3, no. 04 (November 1, 1988): 508–14. http://dx.doi.org/10.2118/15022-pa.

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Shtoff, A. V. "Prediction of Oil Production Rate of Jet Pumping Oil Wells From Sample Well Data." SPE Production & Facilities 14, no. 01 (February 1, 1999): 77–80. http://dx.doi.org/10.2118/54537-pa.

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Dissertations / Theses on the topic "Oil wells"

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Akangbou, H. N. "Optimizing oil production in horizontal wells (water/oil cresting in horizontal wells)." Thesis, University of Salford, 2017. http://usir.salford.ac.uk/43678/.

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In recent years, the application of horizontal wells has been predominant in minimizing cresting scenarios due to significant reservoir exposure of its laterals. Cresting is known to occur in horizontal wells when the pressure drop supersedes the hydrostatic pressure existing between the phases in a typical reservoir. Cresting poses problems such as uneconomic oil production rates due to increasing volumes of effluent(s) (unwanted water and or gas) produced with oil over time as well as the overall recovery efficiency of oil reservoirs. Production optimization from crest-affected thick- and thin-oil rim homogeneous reservoirs were investigated experimentally by considering the effect of varying the inclined sections of a horizontal well at low angles of inclination (15o-30o), initial surface pressures (-4.351Psig), lateral length in reservoir (lr, = 0.305 m) and oil viscosity (50 cP) on oil recovery, oil produced and cumulative water produced during cresting. A strong bottom aquifer and considerable gas cap were modeled at constant bottom water injection rate of 41.68 cm3/s and at atmospheric pressure (14.7 Psi) respectively. An experimental proactive cresting control technique based on reservoir wettability, gravity segregation and effluent(s) breakthrough times were investigated for cresting control in thick- and thin-oil rim homogeneous reservoirs, using an electromagnetic valve installation. Numerical simulations were considered using Particle Image Velocimetry (PIV) to the determine the velocity of captured water cresting images and Computational Fluid Dynamics (CFD) to validate the oil withdrawal rate, Gas-Oil-Contact (GOC) and Water-Oil-Contact (WOC) by applying boundary conditions from the physical model. From results of varying the inclined section of the horizontal well, the Short radius wells with 30o angle of inclination and ratio of vertical displacement of the inclined section to reservoir height (Vd/Hr) of 0.079 resulted in 177.75 cm3 increment in oil recovered and reduction in cumulative water produced (258 cm3) at a production time of 300 s in thick-oil rim reservoirs while 250 cm3 increment in oil was observed with 356 cm3 reduction in cumulative water produced at a production time of 495 s in thick-oil rim reservoirs with Vd/Hr, 0.063. Further increment of 108.91 cm3 in oil produced and reduction in cumulative water produced (183.99 cm3), was observed when cresting was controlled proactively in thick-oil rim reservoirs. From varying the inclined section of the horizontal well, increment in oil produced of 163 cm3 and 134 cm3 cumulative reduction in produced water were observed at Vd/Hr equals 0.079 in thin-oil rim reservoirs at a simulation time of 210 s while a lower oil increment of 6.84 cm3 and cumulative water reduction of 10.98 cm3 were observed in thin-oil rim reservoirs when controlled proactively. The over predicted quantitative results as high as 75.06% using the CFD model compared with experimental data were due to two-dimensional (2D) model limitations in porous media as well as the corresponding grain sizes. To exemplify, for WOC the predicted results was about 28.56% compared to experimental data at 4.5 s. The average velocity profile from PIV analysis increased steadily from 0.113 to 2.08E-15 m/s from 10 to 90 s.
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Ozkan, Erdal. "Performance of horizontal wells /." Access abstract and link to full text, 1988. http://0-wwwlib.umi.com.library.utulsa.edu/dissertations/fullcit/8825498.

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Nunsavathu, Upender Naik. "Productivity index of multilateral wells." Morgantown, W. Va. : [West Virginia University Libraries], 2006. https://eidr.wvu.edu/etd/documentdata.eTD?documentid=4702.

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Thesis (M.S.)--West Virginia University, 2006.
Title from document title page. Document formatted into pages; contains xi, 106 p. : ill. (some col.). Includes abstract. Includes bibliographical references (p. 104-106).
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Mishra, Nekkhil. "Investigation of hole cleaning parameters using computational fluid dynamics in horizontal and deviated wells." Morgantown, W. Va. : [West Virginia University Libraries], 2007. https://eidr.wvu.edu/etd/documentdata.eTD?documentid=5111.

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Thesis (M.S.)--West Virginia University, 2007.
Title from document title page. Document formatted into pages; contains x, 65 p. : ill. (some col.). Includes abstract. Includes bibliographical references (p. 58-60).
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Kaparthi, Prashanth. "Kinematic synthesis of a well service machine." Morgantown, W. Va. : [West Virginia University Libraries], 2001. http://etd.wvu.edu/templates/showETD.cfm?recnum=2244.

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Thesis (M.S.)--West Virginia University, 2001.
Title from document title page. Document formatted into pages; contains viii, 64 p. : ill. (some col.). Includes abstract. Includes bibliographical references (p. 63-64).
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Cheung, Lok Yee Geraldine. "Micromechanics of sand production in oil wells." Thesis, Imperial College London, 2010. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.528300.

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Laderian, Asghar. "Prediction of temperature profile in oil wells." Thesis, University of Newcastle Upon Tyne, 1991. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.315615.

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GOMES, DALILA DE SOUSA. "MULTIPHASE FLOW SIMULATOR FOR OIL PRODUCTION WELLS." PONTIFÍCIA UNIVERSIDADE CATÓLICA DO RIO DE JANEIRO, 2015. http://www.maxwell.vrac.puc-rio.br/Busca_etds.php?strSecao=resultado&nrSeq=26315@1.

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PONTIFÍCIA UNIVERSIDADE CATÓLICA DO RIO DE JANEIRO
CONSELHO NACIONAL DE DESENVOLVIMENTO CIENTÍFICO E TECNOLÓGICO
Sistemas de escoamento multifásico se formam ao longo de um poço de produção de petróleo. A análise do comportamento do escoamento através da coluna de produção é realizada com o apoio de ferramentas computacionais e é essencial para o projeto e operação de um sistema de produção de petróleo. Os simuladores comerciais disponíveis para esse tipo de análise exigem aquisição de licença, cujo custo é elevado, restringindo seu uso às grandes companhias petrolíferas e aos renomados institutos de pesquisa. Além disso, esses programas não permitem a visualização da metodologia utilizada para o tratamento do problema físico e para a solução numérica empregada, e nem a alteração de parâmetros internos, tornando seu uso restrito a certas classes de problemas. Apesar da grande demanda e utilidade desse tipo de software ainda há poucos trabalhos desenvolvidos nessa área. Esta pesquisa tem como objetivo apresentar o desenvolvimento de um simulador de escoamento multifásico simplificado e aberto, com aplicação na otimização da produção de óleo e gás. Dentre as aplicações do programa podemos citar a obtenção das curvas de gradiente de pressão e a otimização de gás-lift. Um estudo paramétrico foi conduzido, mostrando a influência de parâmetros como, por exemplo, o diâmetro da tubulação. Os resultados obtidos foram comparados com a literatura e são fisicamente coerentes. Sendo assim, o programa desenvolvido mostra-se promissor.
Multiphase flow systems are formed along an oil production well. The analysis of the flow behavior through the production column is performed with the aid of computational tools, and is very important to the design and optimization of the oil well production operation. In general, the commercial softwares available to analyze this process are very expensive, which restrict its use to some particular companies. In addition, the methodology used to analyze the physical problem, and the numerical solution are fixed and closed, which restrict its use to certain classes of problems, since it is not possible to change or improve the numerical solution. Despite the great demand and use of this kind of software, there are few researches in this area. This research aims to present the development of a simplified multiphase flow simulator open to public, with application to the optimization of oil and gas production wells. Among the applications are the plot of pressure-distribution curves and the optimization of gas-lift. A parametric study is performed, showing the influence of some governing parameters, such as tubing diameter, in the production flow rate. The results obtained were compared with pertinent literature and are physically reasonable, showing that the software developed is promising.
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ALCOFRA, ELISA LAGE MODESTO. "ANNULAR PRESSURE BUILD-UP IN OIL WELLS." PONTIFÍCIA UNIVERSIDADE CATÓLICA DO RIO DE JANEIRO, 2014. http://www.maxwell.vrac.puc-rio.br/Busca_etds.php?strSecao=resultado&nrSeq=35522@1.

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PONTIFÍCIA UNIVERSIDADE CATÓLICA DO RIO DE JANEIRO
O projeto de dimensionamento dos revestimentos na indústria de óleo e gás deve garantir a integridade do poço ao longo de todo o seu ciclo de vida, que pode ser de várias décadas. Um carregamento importante a ser considerado surge em consequência da produção, que movimenta os fluidos desde o reservatório até a superfície, aquecendo as partes mais rasas do poço. Este processo de aquecimento expande os fluidos de perfuração e completação que foram confinados nos anulares durante o processo de construção do poço. Esta mudança de volume do fluido é contida pela rigidez dos elementos que o mantém confinado e essa resistência à livre expansão do fluido provoca um aumento de pressão. Em alguns casos, a pressão pode tornar-se tão grande que pode levar o revestimento a colapsar, levando ao abandono de poços e a grandes perdas. Este fenômeno de aumento da pressão é conhecido na indústria do petróleo como anular pressure build-up (APB). O presente trabalho apresenta um modelo térmico para determinar o perfil de temperatura e pressão do fluido monofásico escoando em regime permanente na coluna de produção e a distribuição de temperatura ao longo de todos os elementos do poço. Como os revestimentos não são perfeitamente rígidos, um aumento de temperatura e pressão no poço acarreta na variação do volume do anular, os quais são avaliados de forma acoplada, pois a variação de volume de um anular influencia no outro, assim como os deslocamentos dos revestimentos. O estudo compara os resultados obtidos com um aplicativo comercial, apresentando boa concordância. Além disso, uma análise de sensibilidade é realizada para fornecer uma melhor compreensão do fenômeno.
Casing design projects must ensure well integrity throughout its life, which can be as long as several decades. An important load to be considered appears as a consequence of production. During production, the annuli became heated from the transfer of bottom hole temperature up the well by the produced fluids. With heat-up, the fluids trapped in the annulus began to thermally expand. The expansion induces a volume enlargement, which is restrained by the stiffness of the well structure. This resistance to fluid free expansion keep the fluid confined and can produce a substantial pressure increase. In some cases, pressure may become so great that it can collapse casing, leading to well abandonment and large losses. This pressure increase phenomenon is well-known in the oil industry as annular pressure build-up (APB). In the present study, a monophasic state-state thermal model was developed to determine the oil temperature profile in the tubing and the temperature profile in all structures of the well. As casings are not perfectly rigid, temperature and pressure increase in the well results in annular volume change. Because the well consists of a sequence of casing strings that define the well annuli, the modeling of casing strains should be based on a systematic approach that considers the interaction among the various strings. The study compares results to those obtained with a commercial computer application, presenting good agreement. Further, a sensitivity analysis is performed to provide a better understanding of the phenomenon.
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Gessel, Gregory M. "A New Method for Treating Wells in Reservoir Simulation." Diss., CLICK HERE for online access, 2007. http://contentdm.lib.byu.edu/ETD/image/etd1902.pdf.

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Books on the topic "Oil wells"

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Aadnøy, Bernt Sigve. Modern well design. Houston, Tex: Gulf Pub. Co., 1997.

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Aadnøy, Bernt Sigve. Modern well design. Rotterdam, Netherlands: A. A. Balkema, 1996.

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Rogachev, M. K. Borʹba s oslozhnenii︠a︡mi pri dobyche nefti. Moskva: Nedra, 2006.

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Enjiniaringu Shinkō Kyōkai. Sekiyu Kaihatsu Kankyō Anzen Sentā., ed. Heisei 18-nendo sekiyu oyobi tennen gasu kōzan kōsei haishi kijun chōsa hōkokusho. [Tokyo]: Enjiniaringu Shinkō Kyōkai Sekiyu Kaihatsu Kankyō Anzen Sentā, 2007.

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Institute, American Petroleum, ed. Well completions and footage drilled in the United States, 1970-1982. Washington, D.C. (1220 L St., N.W., Washington 20005): American Petroleum Institute, 1985.

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Graves, W. Gordon. World Oil mature oil & gas wells downhole remediation handbook: A treatise on reliable techniques to extend the life of mature oil and gas wells. Houston, Tex: Gulf Pub. Co., 2004.

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Urazaev, K. A. Osobennosti nasosnoĭ dobychi nefti na mestorozhdenii︠a︡kh Zapadnoĭ Sibiri. Moskva: OAO "VNIIOĖNG", 1997.

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Society of Petroleum Engineers (U.S.), ed. Horizontal wells. Richardson, Tex: Society of Petroleum Engineers, 1998.

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Terry, Brittenham, Moore Preston L, and Society of Petroleum Engineers (U.S.), eds. Advanced well control. Richardson, Tex: Society of Petroleum Engineers, 2003.

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Saroi︠a︡n, A. E. Obsadnai︠a︡ kolonna dli︠a︡ nefti︠a︡nykh i gazovykh skvazhin =: Casing for oil and gas wells. San Francisco: [s.n.], 2007.

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Book chapters on the topic "Oil wells"

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Dai, Caili, Qing You, Mingwei Zhao, Guang Zhao, and Fulin Zhao. "Water Shutoff in Oil Wells." In Principles of Enhanced Oil Recovery, 79–100. Singapore: Springer Nature Singapore, 2023. http://dx.doi.org/10.1007/978-981-99-0193-7_4.

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Spreux, Alain, and André Jourdan. "Horizontal Wells and Reservoir Management Strategy." In The European Oil and Gas Conference, 14–22. Dordrecht: Springer Netherlands, 1991. http://dx.doi.org/10.1007/978-94-010-9844-1_5.

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Dai, Caili, Qing You, Mingwei Zhao, Guang Zhao, and Fulin Zhao. "Profile Control and Flooding of Water Injection Wells." In Principles of Enhanced Oil Recovery, 49–78. Singapore: Springer Nature Singapore, 2023. http://dx.doi.org/10.1007/978-981-99-0193-7_3.

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Karev, Vladimir, Yuri Kovalenko, and Konstantin Ustinov. "Stress-Strain State of Rocks." In Geomechanics of Oil and Gas Wells, 1–24. Cham: Springer International Publishing, 2019. http://dx.doi.org/10.1007/978-3-030-26608-0_1.

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Karev, Vladimir, Yuri Kovalenko, and Konstantin Ustinov. "Directional Unloading Method is a New Approach to Enhancing Oil and Gas Well Productivity." In Geomechanics of Oil and Gas Wells, 155–66. Cham: Springer International Publishing, 2019. http://dx.doi.org/10.1007/978-3-030-26608-0_10.

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Karev, Vladimir, Yuri Kovalenko, and Konstantin Ustinov. "Deformation and Fracture of Rocks in the Presence of Filtration." In Geomechanics of Oil and Gas Wells, 25–34. Cham: Springer International Publishing, 2019. http://dx.doi.org/10.1007/978-3-030-26608-0_2.

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Karev, Vladimir, Yuri Kovalenko, and Konstantin Ustinov. "Mechanical and Mathematical, and Experimental Modeling of Oil and Gas Well Stability." In Geomechanics of Oil and Gas Wells, 35–60. Cham: Springer International Publishing, 2019. http://dx.doi.org/10.1007/978-3-030-26608-0_3.

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Karev, Vladimir, Yuri Kovalenko, and Konstantin Ustinov. "Equipment for Studying Deformation and Strength Properties of Rocks in Triaxial Loading." In Geomechanics of Oil and Gas Wells, 61–70. Cham: Springer International Publishing, 2019. http://dx.doi.org/10.1007/978-3-030-26608-0_4.

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Karev, Vladimir, Yuri Kovalenko, and Konstantin Ustinov. "Loading Programs for Rock Specimens on Triaxial Independent Loading Test System (TILTS)." In Geomechanics of Oil and Gas Wells, 71–83. Cham: Springer International Publishing, 2019. http://dx.doi.org/10.1007/978-3-030-26608-0_5.

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Karev, Vladimir, Yuri Kovalenko, and Konstantin Ustinov. "Dependence of Permeability on Stress State." In Geomechanics of Oil and Gas Wells, 85–96. Cham: Springer International Publishing, 2019. http://dx.doi.org/10.1007/978-3-030-26608-0_6.

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Conference papers on the topic "Oil wells"

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Mavletdinov, M. G. "Experience in the development of oil and oil and gas deposits using horizontal and multilateral wells." In Horizontal Wells 2021. European Association of Geoscientists & Engineers, 2021. http://dx.doi.org/10.3997/2214-4609.202154026.

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Kikuchi, Shuichi. "2D and 3D Well Planning for Horizontal Wells." In Middle East Oil Show. Society of Petroleum Engineers, 1993. http://dx.doi.org/10.2118/25647-ms.

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Apasov, G. T., D. A. Borisov, E. V. Voevoda, M. Y. Gvozdev, V. A. Gribanov, A. V. Yelesin, D. S. Loginova, and D. A. Reshetnikov. "Management of the development of the Tazovsky oil and gas condensate field with a thin oil rim of high-viscosity oil with a massive gas cap." In Horizontal Wells 2021. European Association of Geoscientists & Engineers, 2021. http://dx.doi.org/10.3997/2214-4609.202154064.

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Haddad, S. H., and K. Sonrexa. "Simulation of Artificially Fractured Wells With Single-Well Models." In Middle East Oil Show. Society of Petroleum Engineers, 1991. http://dx.doi.org/10.2118/21338-ms.

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Agishev, A., and A. Nurgaliev. "Performance of casing connection for horizontal oil wells." In Horizontal Wells 2021. European Association of Geoscientists & Engineers, 2021. http://dx.doi.org/10.3997/2214-4609.202154082.

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Kovalenko, Igor Victorovich. "Well Test Analysis of Horizontal Wells and Vertical Wells with Hydraulic Fracturing Applied in Heavy Oil Fields." In SPE Heavy Oil Conference Canada. Society of Petroleum Engineers, 2012. http://dx.doi.org/10.2118/156936-ms.

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El-Banbi, Ahmed H., and William D. McCain. "Sampling Volatile Oil Wells." In SPE Production and Operations Symposium. Society of Petroleum Engineers, 2001. http://dx.doi.org/10.2118/67232-ms.

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Hiscock, B., L. Hinrichs, B. M. Banack, and B. Rapati. "Methodology for In-Well DTS Verifications in SAGD Wells." In SPE Canada Heavy Oil Technical Conference. Society of Petroleum Engineers, 2015. http://dx.doi.org/10.2118/174487-ms.

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Dash, T., D. W. Scott, and C. K. Kwok. "Using Type Wells to Economically Schedule DUC Well Completions." In SPE Oklahoma City Oil and Gas Symposium. Society of Petroleum Engineers, 2017. http://dx.doi.org/10.2118/185109-ms.

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Magalhaes, Fellipe Vieira, Ding Zhu, Shahram Amini, and Peter P. Valko. "Optimization of Fractured Well Performance of Horizontal Gas Wells." In International Oil Conference and Exhibition in Mexico. Society of Petroleum Engineers, 2007. http://dx.doi.org/10.2118/108779-ms.

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Reports on the topic "Oil wells"

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Noll, L. Treating paraffin deposits in producing oil wells. Office of Scientific and Technical Information (OSTI), January 1992. http://dx.doi.org/10.2172/6129696.

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Noll, L. Treating paraffin deposits in producing oil wells. Office of Scientific and Technical Information (OSTI), January 1992. http://dx.doi.org/10.2172/10114361.

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Huizinga, B. J. Geochemical data for 5 Husky Oil NPRA wells. Alaska Division of Geological & Geophysical Surveys, January 2006. http://dx.doi.org/10.14509/19505.

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Edgar, Dorland E., Robert W. Peters, Donald O. Johnson, P. David Paulsen, and Wayne Roberts. Acoustic Energy: An Innovative Technology for Stimulating Oil Wells. Office of Scientific and Technical Information (OSTI), April 2006. http://dx.doi.org/10.2172/883060.

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Piggott, Neil. Geochemical analysis of cuttings from North Slope oil/gas exploratory wells. Alaska Division of Geological & Geophysical Surveys, 1998. http://dx.doi.org/10.14509/19128.

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Oppenheimer, C. H., and F. K. Hiebert. Microbiological techniques for paraffin reduction in producing oil wells: Final report. Office of Scientific and Technical Information (OSTI), April 1989. http://dx.doi.org/10.2172/6308075.

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Huizinga, B. J. Geochemical data for the NPRA wells; which includes an HC-Show (Hydrocarbon-Show) evaluation for 4 Husky Oil NPR Operations Inc. wells, and Source-Rock evaluation for 4 Husky Oil NPR Operations Inc. wells. Alaska Division of Geological & Geophysical Surveys, January 2006. http://dx.doi.org/10.14509/19523.

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Wilson, Mike. Core permeability and porosity determinations for the following North Slope wells: Husky Oil NPR Operations Ikpikpuk Test Well #1, Husky Oil NPR Operations Inigok Test Well #1, Husky Oil Operations East Simpson Test Well #1, and Husky Oil NPR Operations East Simpson Test Well #2. Alaska Division of Geological & Geophysical Surveys, 1999. http://dx.doi.org/10.14509/19131.

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Price, Donald. SM-403-148100-R01 Mineral Wells 2012 RAM Gas and Oil Leak Detection Field Study Results. Chantilly, Virginia: Pipeline Research Council International, Inc. (PRCI), December 2015. http://dx.doi.org/10.55274/r0010851.

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Abstract:
In June 2012, the RAM Program conducted a comprehensive field study to evaluate the performance of current off the shelf sensor technologies for detecting gas and oil leaks on pipelines. This study had three key objectives: 1. Evaluate the capabilities of current technologies that are offered commercially for methane leak detection monitoring using standard pipeline patrol aircraft 2. Provide a test location for development of emerging technologies that are not yet commercially available for pipeline leak detection 3. Assess the feasibility of using airborne sensors to detect staged liquid oil leaks The field study was conducted on two of Enbridge�s operating pipelines located near Mineral Wells, Texas. This location provided realistic conditions for assessing the capabilities and limitations of automated sensor systems that are currently available for leak detection. Three airborne leak detection vendors (Lasen, Pergam, and New Era Technology), and one ground vehicle vendor (Picarro), completed the field study. The field study was performed as part of the 2012 PRCI RAM program that is primarily focused on leak detection technologies using aerial platforms. The study tested a range of sensors designed for gas leak detection using systems mounted on helicopters and fixed wing aircraft. Enbridge staged a series of controlled gas releases simulating pipeline gas leaks. Qualified operators released a series of prescribed natural gas leaks from 8 known locations along the pipelines in order to simulate transmission leaks of varying sizes. Additionally, Enbridge placed 8 liquid petroleum targets along the test pipelines. These gas and oil targets allowed for a direct comparison of technology performance against a known set of conditions. Standard leak patrol methods (ground survey with foot patrol) were also used to identify any emission sources other than the controlled releases. The results from the field study show that 3 of the 4 vendor sensor technologies tested are now feasible alternatives for gas leak detection. The findings for liquid leak detection were promising, but inconclusive due to plume overlaps between gas and oil targets. The sensors used by the vendors in this field test were optimized for detecting methane gas and not oil vapors. Therefore, until additional studies are performed on liquid hydrocarbon volatilization, it is premature to conclude that the tested technologies are or are not appropriate for oil leak detection.
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Snowdon, L. R., and M. G. Fowler. Oil show analyzer, Rock-Eval and toc data for six Scotian Shelf Wells. Natural Resources Canada/ESS/Scientific and Technical Publishing Services, 1986. http://dx.doi.org/10.4095/130180.

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