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Relevant bibliographies by topics / Petroleum engineering

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Academic literature on the topic 'Petroleum engineering'

Author: Grafiati

Published: 4 June 2021

Last updated: 9 June 2025

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Journal articles on the topic "Petroleum engineering"

1

Koščak Kolin, Sonja. "BOOK REVIEW "PETROLEUM PRODUCTION ENGINEERING"." Rudarsko-geološko-naftni zbornik 31, no. 1 (September 1, 2016): 87–88. http://dx.doi.org/10.17794/rgn.2016.3.7.

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Papanastasiou, Panos. "Geomechanics in Petroleum Engineering." International Journal of Geomechanics 4, no. 1 (March 2004): 1. http://dx.doi.org/10.1061/(asce)1532-3641(2004)4:1(1).

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Yupu, WANG, ZHANG Jiayi, and DENG Hongtao. "The Application of Big Data Technology in Petroleum Engineering Information System." Sustainability in Environment 9, no. 3 (August 2, 2024): p92. http://dx.doi.org/10.22158/se.v9n3p92.

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With the rapid development of information technology, big data technology has been widely applied in various industries, and petroleum engineering information systems are no exception. This article aims to explore the application of big data technology in the information system of petroleum engineering, and analyze its role in improving the efficiency and decision-making level of petroleum engineering management. This article provides an overview of the basic concepts and core components of big data technology, including data collection, storage, processing, analysis, and visualization techniques. It introduces the main components of petroleum engineering information systems and the current challenges they face. Through specific cases, this article elaborates on the practical application of big data technology in oilfield development, drilling engineering, and production management, demonstrating the significant advantages of big data in real-time monitoring, parameter optimization, fault prediction, and production analysis. This article discusses the challenges faced by the application of big data technology in petroleum engineering information systems, such as data quality, security and privacy, and technical talent, and proposes corresponding countermeasures. This article looks forward to the future application prospects of big data technology in petroleum engineering, emphasizing the importance of the combination and innovation of emerging technologies in promoting the development of informationization and intelligence in petroleum engineering. Through this study, we hope to provide valuable references for the optimization and innovation of petroleum engineering information systems.

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Amadi, Azubuike H., Paul O. Okafor, Victor D. Ola, Prosper O. Umukoro, Chiedozie V. Oluigbo, David U. Robinson, and Kehinde E. Ajayi. "Pedagogy of Petroleum Engineering in Nigeria." European Journal of Education and Pedagogy 3, no. 3 (June 21, 2022): 257–63. http://dx.doi.org/10.24018/ejedu.2022.3.3.370.

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The petroleum industry in Nigeria contributes a huge percentage to the national revenue of the country, to the extent that budgets are being passed based on the oil price dynamics. With the importance the petroleum sector has attained in Nigeria, it is expected that the country's pedagogy will reflect the value it contributes to the national table. However, reviews, surveys, and works of literature have shown otherwise. As a result, this study emphasizes the importance of petroleum engineering pedagogy in-country as an oil-producing country, the university curriculum of petroleum engineering in Nigeria was also examined (with a particular focus on the impact of poor curriculum on national development), and the dynamics between the university, industry and government were critically discussed and recommended practices for improving petroleum engineering pedagogy were made. This study targets national development and control over its own resources through a knowledge economy and seamless dynamics of information within the oil and gas industry. The Nigerian government, through the Federal Ministry of Education, is further expected to capitalize on the outcomes of this research for curriculum review of petroleum engineering and related courses offered in-country to foster sustainability in a competing global society.

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Mody, Rustom K. "Petroleum Engineering - The Best Profession." Journal of Petroleum Technology 71, no. 03 (March 1, 2019): 17–18. http://dx.doi.org/10.2118/0319-0017-jpt.

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Hendrickson, Chris. "Petroleum Prices and Transportation Engineering." Journal of Transportation Engineering 134, no. 9 (September 2008): 359–60. http://dx.doi.org/10.1061/(asce)0733-947x(2008)134:9(359).

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Sheremetov, Leonid, Matías Alvarado, René Bañares-Alcántara, Fred Aminzadeh, and G. Ali Mansoori. "Intelligent computing in petroleum engineering." Journal of Petroleum Science and Engineering 47, no. 1-2 (May 2005): 1–3. http://dx.doi.org/10.1016/j.petrol.2005.01.001.

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Bennett, Gary F. "Environmental control in petroleum engineering." Journal of Hazardous Materials 54, no. 3 (July 1997): 262–63. http://dx.doi.org/10.1016/s0304-3894(97)82803-8.

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Al-Awad, Musaed N. J. "New frontiers in petroleum engineering." Journal of King Saud University - Engineering Sciences 28, no. 2 (July 2016): 121–22. http://dx.doi.org/10.1016/j.jksues.2016.05.001.

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Griffiths, A. E. "Examples of Petroleum Engineering Objects." SPE Computer Applications 7, no. 03 (May 1, 1995): 68–73. http://dx.doi.org/10.2118/27556-pa.

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Dissertations / Theses on the topic "Petroleum engineering"

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Horsfield, Mark Andrew. "Nuclear Magnetic Resonance in petroleum engineering." Thesis, University of Cambridge, 1989. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.334172.

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Glanfield, Thomas H. 1980. "Energy required to produce petroleum products from oil sand versus other petroleum sources." Thesis, Massachusetts Institute of Technology, 2002. http://hdl.handle.net/1721.1/29589.

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Rudraraju, VRS Raju. "Ultrasonic Data Communication through Petroleum." University of Akron / OhioLINK, 2010. http://rave.ohiolink.edu/etdc/view?acc_num=akron1271703312.

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Leamon, Gregory Robert Petroleum Engineering Faculty of Engineering UNSW. "Petroleum well costs." Awarded by:University of New South Wales. School of Petroleum Engineering, 2006. http://handle.unsw.edu.au/1959.4/30599.

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This is the first academic study of well costs and drilling times for Australia???s petroleum producing basins, both onshore and offshore. I analyse a substantial database of well times and costs sourced from government databases, industry and over 400 recent well completion reports. Three well phases are studied - Pre-Spud, Drilling and Completion. Relationships between well cost factors are considered, including phase time, phase cost, daily cost, rig day rate, well depth, basin, rig type, water depth, well direction, well objective (e.g. exploration), and type of completion (P&A or producer). Times and costs are analysed using scatter plots, frequency distributions, correlation and regression analyses. Drilling times are analysed for the period 1980 to 2004. Well time and variability in well time tend to increase exponentially with well depth. Technical Limits are defined for both onshore and offshore drilling times to indicate best performance. Well costs are analysed for the period 1996 to 2004. Well costs were relatively stable for this period. Long term increases in daily costs were offset to some extent by reductions in drilling times. Onshore regions studied include the Cooper/Eromanga, Surat/Bowen, Otway and Perth Basins. Offshore regions studied include the Carnarvon Basin shallow and deepwater, the Timor Sea and Victorian Basins. Correlations between regional well cost and well depth are usually high. Well costs are estimated based on well location, well depth, daily costs and type of completion. In 2003, the cost of exploration wells in Australia ranged from A$100,000 for shallow coal seam gas wells in the Surat/Bowen Basins to over A$50 million for the deepwater well Gnarlyknots-1 in the Great Australian Bight. Future well costs are expected to be substantially higher for some regions. This study proposes methods to index historical daily costs to future rig day rates as a means for estimating future well costs. Regional well cost models are particularly useful for the economic evaluation of CO2 storage sites which will require substantial numbers of petroleum-type wells.

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Silveira, Mastella Laura. "Semantic exploitation of engineering models : application to petroleum reservoir models." Centre de géosciences (Fontainebleau, Seine et Marne), 2010. https://pastel.hal.science/pastel-00005770.

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Ce travail propose des solutions innovantes en vue de l'exploitation des modèles d'ingénierie hétérogènes. Il prend pour exemple le domaine de la prospection pétrolière. Les stratégies de prospection sont élaborées à partir de représentations tridimensionnelles du sous-sol appelées modèles géologiques. Ceux-ci reposent sur un grand nombre de données hétérogènes générées au fur et à mesure de la conduite de l'exploration par des activités telles que la prospection séismique, les forages, l'interprétation des logs de puits. A fin d'optimisation, les utilisateurs finaux souhaitent, pouvoir retrouver et réutiliser à tout moment les données et les interprétations attachés aux différents modèles successivement générés. Les approches d' intégration des connaissances susceptibles d'être mises en œuvre pour résoudre ce défi, doivent être dissociées aussi bien des sources et des formats de données que des outils logiciels en constante évolution. Pour cela, nous proposons d'utiliser l'annotation sémantique, technique courante du Web sémantique permettant d'associer la connaissance à des ressources au moyen d' "étiquettes sémantiques". La sémantique ainsi explicitée est définie par un certain nombre d' ontologies de domaine, qui, selon la définition classique, correspondent à autant "de spécifications formelles de la conceptualisation" des domaines considérés. En vue d'intégrer les modèles d'ingénierie considérés, nous proposons une architecture, qui permet de relier des concepts appartenant respectivement à des ontologies locales et à une ontologie globale. Les utilisateurs peuvent ainsi avoir une vision globale, intégrée et partagée de chacun des domaines impliqués dans chaîne de modélisation géologique. Un prototype a été développé qui concerne la première étape de la chaîne de modélisation (interprétation séismique). Les expérimentations réalisées prouvent que, grâce à l'approche proposée, les experts peuvent, en utilisant le vocabulaire de leur domaine d'expertise, formuler des questions et obtenir des réponses appropriées<br>This work intends to propose innovative solutions for the exploitation of heterogeneous models in engineering domains. It pays a special attention to a case study related to one specific engineering domain: petroleum exploration. Experts deal with many petroleum exploration issues by building and exploiting three-dimensional representations of underground (called earth models). These models rest on a large amount of heterogeneous data generated every day by several different exploration activities such as seismic surveys, well drilling, well log interpretation and many others. Considering this, end-users wish to be able to retrieve and re-use at any moment information related to data and interpretations in the various fields of expertise considered along the earth modeling chain. Integration approaches for engineering domains needs to be dissociated from data sources, formats and software tools that are constantly evolving. Our solution is based on semantic annotation, a current Web Semantic technique for adding knowledge to resources by means of semantic tags. The "semantics" attached by means of some annotation is defined by ontologies, corresponding to "formal specifications of some domain conceptualization". In order to complete engineering model exploitation, it is necessary to provide model integration. Correspondence between models in the ontology level is made possible thanks to semantic annotation. An architecture, which maps concepts from local ontologies to some global ontology, then ensures that users can have an integrated and shared global view of each specific domain involved in the engineering process. A prototype was implemented considering the seismic interpretation activity, which corresponds to the first step of the earth modeling workflow. The performed experiments show that, thanks to our solution, experts can formulate queries and retrieve relevant answers using their knowledge-level vocabulary

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Sousa, Bruno Rangel de 1985. "Análise de teste em poços inclinados." [s.n.], 2012. http://repositorio.unicamp.br/jspui/handle/REPOSIP/263149.

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Orientador: Rosângela Barros Zanoni Lopes Moreno<br>Dissertação (mestrado) - Universidade Estadual de Campinas, Faculdade de Engenharia Mecânica e Instituto de Geociências<br>Made available in DSpace on 2018-08-21T10:32:47Z (GMT). No. of bitstreams: 1 Sousa_BrunoRangelde_M.pdf: 2665889 bytes, checksum: d124b91d0b604845255264f303b44b22 (MD5) Previous issue date: 2012<br>Resumo: Apresenta-se nesta dissertação um estudo sobre o comportamento transitório da pressão em poços inclinados submetidos a teste de poço. A partir de referências disponíveis na literatura, são apresentadas soluções analíticas e semi-analíticas, onde é adotado o modelo de escoamento uniforme como condição de contorno no poço. Neste estudo é considerado um reservatório de extensão radial infinita com limites verticais impermeáveis. A partir da solução analítica são apresentadas curvas típicas para diferentes ângulos de inclinação do poço e espessura adimensional da formação. As análises das curvas típicas indicam três regimes de escoamento: radial inicial, radial de transição e radial infinito, onde, no melhor conhecimento deste autor, o regime de escoamento radial de transição é introduzido nesta dissertação. A partir da solução semi-analítica, derivada no domínio de Laplace, são desenvolvidas assíntotas para tempo-curto e tempo-longo. Esta dissertação ainda apresenta um procedimento alternativo para interpretar os dados transitórios da pressão em poços inclinados. O desenvolvimento deste procedimento foi baseado na técnica TDS (Tiab's Direct Synthesis), onde é possível interpretar os dados de pressão através de uma análise direta da curva de derivada. As soluções aqui apresentadas fornecem uma alternativa acessível à completa modelagem numérica - utilizada em pacotes comerciais para interpretação de teste de pressão<br>Abstract: A study on the transient pressure behavior it is presented in this dissertation for slanted well test analysis. From references available in the literature, analytical and semi-analytical solutions are presented for the uniform flow boundary condition at the well. In this study is considered an infinite radial extent reservoir limited with vertical impermeable boundaries. Type curves are presented for different slant angles of the well and dimensionless formation thickness. From the analysis of type curves are observed three flow regimes: early time radial flow, transition radial flow and late time infinite-acting radial flow. For the best knowledge of the author, the transition radial flow regime is introduced in this dissertation for the first time. From the semi-analytical solution, derived in the Laplace domain, asymptotic solutions are developed for early-time and late-time. It is also presented an alternative procedure for interpreting pressure transient data in slanted wells. The development of this procedure was based on the TDS (Tiab's Direct Synthesis) technique, by where it is possible to interpret the pressure data through a direct analysis of the derived curve. The solutions presented here provide a feasible alternative to full numerical modeling - used in commercial packages for the interpretation of pressure tests<br>Mestrado<br>Reservatórios e Gestão<br>Mestre em Ciências e Engenharia de Petróleo

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Kumar, Ankesh. "Engineering behavior of oil shale under high pressure after thermal treatment." Thesis, IIT, Delhi, 2019. http://eprint.iitd.ac.in:80//handle/2074/8076.

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Roychaudhuri, Basabdatta. "Spontaneous Countercurrent and Forced Imbibition in Gas Shales." Thesis, University of Southern California, 2018. http://pqdtopen.proquest.com/#viewpdf?dispub=10635652.

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<p> In this study, imbibition experiments are used to explain the significant fluid loss, often more than 70%, of injected water during well stimulation and flowback in the context of natural gas production from shale formations. Samples from a 180 ft. long section of a vertical well were studied via spontaneous and forced imbibition experiments, at lab-scale, on small samples with characteristic dimensions of a few cm; in order to quantify the water imbibed by the complex multi-porosity shale system. The imbibition process is, typically, characterized by a distinct transition from an initial linear rate (vs. square root of time) to a much slower imbibition rate at later times. These observations along with contact angle measurements provide an insight into the wettability characteristics of the shale surface. Using these observations, together with an assumed geometry of the fracture system, has made it possible to estimate the distance travelled by the injected water into the formation at field scale. </p><p> Shale characterization experiments including permeability measurements, total organic carbon (TOC) analysis, pore size distribution (PSD) and contact angle measurements were also performed and were combined with XRD measurements in order to better understand the mass transfer properties of shale. The experimental permeabilities measured in the direction along the bedding plane (10<sup> –1</sup>–10<sup>–2</sup> mD) and in the vertical direction (~10<sup>–4</sup> mD) are orders of magnitude higher than the matrix permeabilities of these shale sample (10<sup>–5</sup> to 10<sup> –8</sup> mD). This implies that the fastest flow in a formation is likely to occur in the horizontal direction, and indicates that the flow of fluids through the formation occurs predominantly through the fracture and micro-fracture network, and hence that these are the main conduits for gas recovery. The permeability differences among samples from various depths can be attributed to different organic matter content and mineralogical characteristics, likely attributed to varying depositional environments. The study of these properties can help ascertain the ideal depth for well placement and perforation. </p><p> Forced imbibition experiments have been carried out to better understand the phenomena that take place during well stimulation under realistic reservoir conditions. Imbibition experiments have been performed with real and simulated frac fluids, including deionized (DI) water, to establish a baseline, in order to study the impact on imbibition rates resulting from the presence of ions/additives in the imbibing fluid. Ion interactions with shales are studied using ion chromatography (IC) to ascertain their effect on imbibition induced porosity and permeability change of the samples. It has been found that divalent cations such as calcium and anions such as sulfates (for concentrations in excess of 600 ppm) can significantly reduce the permeability of the samples. It is concluded, therefore, that their presence in stimulating fluids can affect the capillarity and fluid flow after stimulation. We have also studied the impact of using fluoro-surfactant additives during spontaneous and forced imbibition experiments. A number of these additives have been shown to increase the measured contact angles of the shale samples and the fluid recovery from them, thus making them an ideal candidate for additives to use. Their interactions with the shale are further characterized using the Dynamic Light Scattering (DLS) technique in order to measure their hydrodynamic radius to compare it with the pore size of the shale sample.</p><p>

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Johnson, Andrew Charles. "Constructing a Niobrara Reservoir Model Using Outcrop and Downhole Data." Thesis, Colorado School of Mines, 2018. http://pqdtopen.proquest.com/#viewpdf?dispub=10843100.

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<p> The objective of this study is threefold: 1) Build a dual-porosity, geological reservoir model of Niobrara formation in the Wishbone Section of the DJ Basin. 2) Use the geologic static model to construct a compositional model to assess performance of Well 1N in the Wishbone Section. 3) Compare the modeling results of this study with the result from an eleven-well modeling study (Ning, 2017) of the same formation which included the same well. The geologic model is based on discrete fracture network (DFN) model (Grechishnikova 2017) from an outcrop study of Niobrara formation.</p><p> This study is part of a broader program sponsored by Anadarko and conducted by the Reservoir Characterization Project (RCP) at Colorado School of Mines. The study area is the Wishbone Section (one square mile area), which has eleven horizontal producing wells with initial production dating back to September 2013. The project also includes a nine-component time-lapse seismic. The Wishbone section is a low-permeability faulted reservoir containing liquid-rich light hydrocarbons in the Niobrara chalk and Codell sandstone.</p><p> The geologic framework was built by Grechishnikova (2017) using seismic, microseismic, petrophysical suite, core and outcrop. I used Grechishnikova’s geologic framework and available petrophysical and core data to construct a 3D reservoir model. The 3D geologic model was used in the hydraulic fracture modeling software, GOHFER, to create a hydraulic fracture interpretation for the reservoir simulator and compared to the interpretation built by Alfataierge (2017). The reservoir numerical simulator incorporated PVT from a well within the section to create the compositional dual-porosity model in CMG with seven lumped components instead of the thirty-two individual components. History matching was completed for the numerical simulation, and rate transient analysis between field and actual production are compared; the results were similar. The history matching parameters are further compared to the input parameters, and Ning’s (2017) history matching parameters.</p><p> The study evaluated how fracture porosity and rock compaction impacts production. The fracture porosity is a major contributor to well production and the gas oil ratio. The fracture porosity is a major sink for gathering the matrix flow contribution. The compaction numerical simulations show oil production increases with compaction because of the increased compaction drive. As rock compaction increases, permeability and porosity decreases. How the numerical model software, CMG, builds the hydraulic fracture, artificially increases the original oil-in-place and decreases the recovery factor. Furthermore, grid structure impacts run-time and accuracy to the model. Finally, outcrop adds value to the subsurface model with careful qualitative sedimentology and structural extrapolations to the subsurface by providing understanding between the wellbore and seismic data scales.</p><p>

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Alaiyegbami, Ayodele O. "Porescale Investigation of Gas Shales Reservoir Description by Comparing the Barnett, Mancos, and Marcellus Formation." Thesis, University of Louisiana at Lafayette, 2014. http://pqdtopen.proquest.com/#viewpdf?dispub=1557534.

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<p> This thesis describes the advantages of investigating gas shales reservoir description on a nanoscale by using petrographic analysis and core plug petrophysics to characterize the Barnett, Marcellus and Mancos shale plays. The results from this analysis now indicate their effects on the reservoir quality. Helium porosity measurements at confining pressure were carried out on core plugs from this shale plays. SEM (Scanning Electron Microscopy) imaging was done on freshly fractured gold-coated surfaces to indicate pore structure and grain sizes. Electron Dispersive X-ray Spectroscopy was done on freshly fractured carbon-coated surfaces to tell the mineralogy. Extra-thin sections were made to view pore spaces, natural fractures and grain distribution. </p><p> The results of this study show that confining pressure helium porosity values to be 9.6%, 5.3% and 1.7% in decreasing order for the samples from the Barnett, Mancos and Marcellus shale respectively. EDS X-ray spectroscopy indicates that the Barnett and Mancos have a high concentration of quartz (silica-content); while the Mancos and Marcellus contain calcite. Thin section analysis reveals obvious fractures in the Barnett, while Mancos and Marcellus have micro-fractures. </p><p> Based on porosity, petrographic analysis and mineralogy measurements on the all the samples, the Barnett shale seem to exhibit the best reservoir quality.</p>

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Books on the topic "Petroleum engineering"

1

Archer, J. S., and C. G. Wall. Petroleum Engineering. Dordrecht: Springer Netherlands, 1986. http://dx.doi.org/10.1007/978-94-010-9601-0.

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Lake, Larry W. Petroleum engineering handbook. Richardson, TX: Society of Petroleum Engineers, 2006.

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B, Bradley Howard, and Gipson Fred W, eds. Petroleum engineering handbook. Richardson, TX, U.S.A: Society of Petroleum Engineers, 1987.

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Guiming, Ding, ed. Petroleum exploration engineering. Beijing: Petroleum Industry Press, 1997.

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W, Lake Larry, Fanchi John R, and Society of Petroleum Engineers (U.S.), eds. Petroleum engineering handbook. Richardson, TX: Society of Petroleum Engineers, 2006.

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W, Lake Larry, Fanchi John R, and Society of Petroleum Engineers (U.S.), eds. Petroleum engineering handbook. Richardson, TX: Society of Petroleum Engineers, 2006.

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Lake, Larry W. Petroleum engineering handbook. Edited by Fanchi John R and Society of Petroleum Engineers (U.S.). Richardson, TX: Society of Petroleum Engineers, 2006.

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W, Lake Larry, Fanchi John R, and Society of Petroleum Engineers (U.S.), eds. Petroleum engineering handbook. Richardson, TX: Society of Petroleum Engineers, 2006.

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Banerjee, Santanu, Reza Barati, and Shirish Patil, eds. Advances in Petroleum Engineering and Petroleum Geochemistry. Cham: Springer International Publishing, 2019. http://dx.doi.org/10.1007/978-3-030-01578-7.

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Ezekwe, Nnaemeka. Petroleum reservoir engineering practice. Upper Saddle River, NJ: Prentice Hall, 2011.

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Book chapters on the topic "Petroleum engineering"

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Chen, Shengnan. "Petroleum Production Engineering." In Springer Handbook of Petroleum Technology, 501–16. Cham: Springer International Publishing, 2017. http://dx.doi.org/10.1007/978-3-319-49347-3_14.

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Archer, J. S., and C. G. Wall. "Introduction." In Petroleum Engineering, 1–6. Dordrecht: Springer Netherlands, 1986. http://dx.doi.org/10.1007/978-94-010-9601-0_1.

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Archer, J. S., and C. G. Wall. "Reservoir Performance Analysis." In Petroleum Engineering, 157–72. Dordrecht: Springer Netherlands, 1986. http://dx.doi.org/10.1007/978-94-010-9601-0_10.

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Archer, J. S., and C. G. Wall. "Secondary Recovery and Pressure Maintenance." In Petroleum Engineering, 173–90. Dordrecht: Springer Netherlands, 1986. http://dx.doi.org/10.1007/978-94-010-9601-0_11.

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Archer, J. S., and C. G. Wall. "Improved Hydrocarbon Recovery." In Petroleum Engineering, 191–217. Dordrecht: Springer Netherlands, 1986. http://dx.doi.org/10.1007/978-94-010-9601-0_12.

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Archer, J. S., and C. G. Wall. "Factors Influencing Production Operations." In Petroleum Engineering, 218–32. Dordrecht: Springer Netherlands, 1986. http://dx.doi.org/10.1007/978-94-010-9601-0_13.

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Archer, J. S., and C. G. Wall. "Concepts in Reservoir Modelling and Application to Development Planning." In Petroleum Engineering, 233–56. Dordrecht: Springer Netherlands, 1986. http://dx.doi.org/10.1007/978-94-010-9601-0_14.

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Archer, J. S., and C. G. Wall. "Reservoirs." In Petroleum Engineering, 7–19. Dordrecht: Springer Netherlands, 1986. http://dx.doi.org/10.1007/978-94-010-9601-0_2.

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Archer, J. S., and C. G. Wall. "Oilwell Drilling." In Petroleum Engineering, 20–39. Dordrecht: Springer Netherlands, 1986. http://dx.doi.org/10.1007/978-94-010-9601-0_3.

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Archer, J. S., and C. G. Wall. "Properties of Reservoir Fluids." In Petroleum Engineering, 40–61. Dordrecht: Springer Netherlands, 1986. http://dx.doi.org/10.1007/978-94-010-9601-0_4.

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Conference papers on the topic "Petroleum engineering"

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Crouse, P. C. "Petroleum Engineering Manpower Demand." In SPE Annual Technical Conference and Exhibition. Society of Petroleum Engineers, 1989. http://dx.doi.org/10.2118/19868-ms.

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Bourgoyne, A. T. "Petroleum Engineering Manpower Supply." In SPE Annual Technical Conference and Exhibition. Society of Petroleum Engineers, 1988. http://dx.doi.org/10.2118/18336-ms.

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Satrun, Eugene A. "Ergonomics and Petroleum Engineering." In SPE International Conference on Health, Safety, and Environment in Oil and Gas Exploration and Production. Society of Petroleum Engineers, 1998. http://dx.doi.org/10.2118/46758-ms.

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Michael, Andreas. "Excellence in Petroleum Engineering." In SPE Annual Technical Conference and Exhibition. SPE, 2023. http://dx.doi.org/10.2118/214814-ms.

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Abstract The failed merger attempt between SPE and the American Association of Petroleum Geologists (AAPG) in 2020-21 brought about nonsensical calls for rebranding the petroleum engineering (PE) discipline into something like "energy engineering" and by extension SPE into "Society of Professionals in Energy." This led to the writing of "Petroleum Engineers Need a Strong Professional Society" (SPE-210365). I felt a need to combat heavy-consequence-bearing misconceptions promulgated in the PE community, including a field of great importance: education. Someone had to set the record straight. PE academic programs interested in facilitating a smooth transition of their graduates into the industry should work in conjunction with the exploration and production (E&P) sector of the oil and gas (O&G) industry to provide the correct balance between theory and practice in their coursework, ensuring that relevant-E&P-job openings are filled with their graduates. The low PE-student enrollment levels frequently reported may be a manifestation of long-standing issues within the PE higher education. Decisions on things like curricula/syllabi design, along with faculty hiring should be governed by a desire to equip PE graduates with a competitive advantage over non-PE graduates vis-à-vis related-E&P domains.Integrating the many PE subdisciplines (drilling, reservoir, production, and other) in a manner efficient for learning is essential for producing competitive-and-market-attractive young professionals. PE graduates must be cognizant of the basics and fundamentals of their "trade," comfortable in assessing E&P problems efficiently through all their facets. While talks on the transferability of skills that PEs typically feature into peripheral disciplines mainstreams, strengthening the competitive advantage that PE graduates must hold over non-PE graduates is where the focus needs to be. Excellence in PE requires intra-disciplinarism – completeness on all fronts.This paper presents ten "truisms" (cold, hard realities of the modern-day world), providing explanations behind several status quos impacting the PE discipline, directly or indirectly.

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C. Gringarten, A. "Teaching Petroleum Engineering and Petroleum Geoscience at Imperial College." In 64th EAGE Conference & Exhibition. European Association of Geoscientists & Engineers, 2002. http://dx.doi.org/10.3997/2214-4609.201405786.

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Daltaban, T. S., J. S. Archer, and H. Toral. "Petroleum Engineering Studies Educational Model." In Petroleum Computer Conference. Society of Petroleum Engineers, 1989. http://dx.doi.org/10.2118/19145-ms.

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Kinney, Lance, and Catherine Norwood. "Review of Professional Engineering in Petroleum Engineering." In SPE Annual Technical Conference and Exhibition. Society of Petroleum Engineers, 2018. http://dx.doi.org/10.2118/191431-ms.

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Temizel, Cenk, Tayfun Tuna, Bao Jia, Dike Putra, and Raul Moreno. "A Practical Petroleum Engineering Toolkit." In SPE Kuwait Oil & Gas Show and Conference. Society of Petroleum Engineers, 2017. http://dx.doi.org/10.2118/187646-ms.

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Kamal, Medhat M. "Future Need of Petroleum Engineering." In SPE Western Regional Meeting. Society of Petroleum Engineers, 2020. http://dx.doi.org/10.2118/200771-ms.

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Aggour, T., T. Donohue, and D. A. Donohue. "Modernizing Petroleum Engineering Education: A New Global Online Petroleum Engineering University Serving all Universities." In SPE Annual Technical Conference and Exhibition. Society of Petroleum Engineers, 2015. http://dx.doi.org/10.2118/176749-ms.

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Reports on the topic "Petroleum engineering"

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Calhoun, Jr, J. A research agenda for academic petroleum engineering programs. Office of Scientific and Technical Information (OSTI), March 1990. http://dx.doi.org/10.2172/7169330.

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Calhoun, J. C. Jr. A research agenda for academic petroleum engineering programs. [Final report]. Office of Scientific and Technical Information (OSTI), March 1990. http://dx.doi.org/10.2172/10182966.

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Robert, Gillian. PR-420-143719-R01 Commercial Remote Sensing and Spatial Information Technology Applications Program. Chantilly, Virginia: Pipeline Research Council International, Inc. (PRCI), August 2018. http://dx.doi.org/10.55274/r0011508.

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The work described herein is to show the engineering requirements for long term, continuous monitoring of ground movement with satellite radar over a region with natural growth and large variations in ground water. The project provided monitoring of the British Petroleum America Inc. (BP) Olympic pipeline localized to an area of known ground movement in Washington State. This project was part of several projects (ROW-6G, ROW-6D, ROW-3J) that partnered with California Polytechnic University, San Luis Obispo (CalPoly SLO) and Electricore to prepare a white paper that was submitted in response to a solicitation issued by the Research and Innovative Technology Administration (RITA) for research ideas that focused on the Commercial Remote Sensing and Spatial Information (CRS and SI) technologies program for transportation infrastructure development and construction.

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Rana, Arnav, and Sanjay Tiku. PR-214-223806-R01 Guidance for Performing Engineering Critical Assessments for Dents on Natural Gas Pipelines. Chantilly, Virginia: Pipeline Research Council International, Inc. (PRCI), November 2023. http://dx.doi.org/10.55274/r0000044.

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This project builds on mechanical damage (MD) assessment and management tools, developed on behalf of Pipeline Research Council International (PRCI), Interstate Natural Gas Association of America (INGAA), Canadian Energy Pipeline Association (CEPA), American Petroleum Institute (API), other research organizations and individual pipeline operators and included in API RP 1183 [1]. These include dent shape, restraint condition and interacting feature characterization; operational maximum and cyclic internal pressure characterization, screening tools defining non-injurious dent shapes based on pipe size and operating condition, failure pressure and fatigue assessment tools for dents with/without interacting features (e.g., corrosion, welds, gouges) in the restrained and unrestrained condition, and direction on available remedial action and repair techniques. The API RP 1183 [1], has not been adopted by the Pipeline and Hazardous Materials Safety Administration (PHMSA) by reference in code of federal regulations (CFR) 192.712 (c). CFR 192.712 (c) allows pipeline operators to follow certain prescriptive requirements for responding to mechanical damage features or perform an engineering critical assessment (ECA). The requirements of CFR 192.712 (c) provide minimum requirements for what would comprise an acceptable ECA. The objective of this research project is to develop a guidance document containing a practical and defensible set of guidelines and processes to address the CFR 192.712 (c) requirements. The work included: - Description of various dent fatigue life screening and assessment approaches detailing data requirements for the different approaches, - Developing a simplified method for dent fatigue life assessment using operational severity when detailed pressure spectrum data is not available, - Development of a Level 0.75 and 0.75+ screening approach that incorporates dent depth available from in-line inspection (ILI) data, - Developing a screening level methodology to carry out fatigue life assessment of dents with potential gouge where metal loss is conservatively assumed to be a planar crack-like feature.

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Tiku, Sanjay, Arnav Rana, and Binoy John. PR214-223810-R01 Improvement in Dent Assessment and Management Tools. Chantilly, Virginia: Pipeline Research Council International, Inc. (PRCI), September 2024. http://dx.doi.org/10.55274/r0000090.

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This project builds on and supplements existing mechanical damage (MD) assessment and management tools, developed on behalf of Pipeline Research Council International (PRCI), Interstate Natural Gas Association of America (INGAA), Canadian Energy Pipeline Association (CEPA), American Petroleum Institute (API), other research organizations and individual pipeline operators, many of which are included in API Recommended Practice (RP) 1183 (1). Since the assembly of API RP 1183, PRCI has continued its mechanical damage strategic research priority in the development of a greater understanding of the behavior of mechanical damage and the production of data to support engineering assessment. The objective of this research project is to develop and/or modify: - Scaling factors to develop separate safety factors associated with fatigue life prediction of restrained and unrestrained dents, - Modification of dent weld interaction approach to consider distance of welds from the dent peak, and - Development of stress range magnification factor approach for Level 2 assessment similar to other screening life approaches incorporated in API RP 1183.

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Tiku, Sanjay, Binoy John, and Arnav Rana. PR-214-183816-R01 Full-scale Fatigue Testing of Field Dents. Chantilly, Virginia: Pipeline Research Council International, Inc. (PRCI), January 2022. http://dx.doi.org/10.55274/r0012202.

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Significant effort has been spent in understanding dent fatigue behavior and developing engineering assessment tools for dent integrity management involving full-scale dent testing and numerical modeling through Pipeline Research Council International (PRCI), United States Department of Transportation (DOT) and Canadian Energy Pipeline Association (CEPA) sponsored research [1][2][3][4][5]. The results of the research work have been incorporated in American Petroleum Institute (API) recommended practice (RP), API RP 1183 [6]. The assessment tools have been validated and calibrated against full-scale dent fatigue tests. The experimental database of dent full-scale fatigue tests; however, consisted of dents created in the laboratory and the majority of these were created using dome shaped (semi-elliptical end caps) indenters. The current project scope was developed to address the specific gap between fabricated samples developed for full-scale test and real world samples, and to provide further validation of the dent fatigue life assessment methodologies incorporated in API RP 1183[6]. The field dents tested under the current project ranged in depth from 0.6 % to 11 % and included pipe samples with diameters ranging from 10" OD to 40" OD. The experimental data generated using former in-service pipeline samples was used to assess and validate the Level 2 and Level 3 dent fatigue assessment tools incorporated in API RP 1183 and support the improved management of mechanical damage so that dig programs can be better managed and the resources effectively utilized by the operating companies. Related webinar

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Department of Petroleum Engineering and Center for Petroleum and Geosystems Engineering annual report, 1990--1991 academic year. Office of Scientific and Technical Information (OSTI), January 1991. http://dx.doi.org/10.2172/7152752.

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Department of Petroleum Engineering and Center for Petroleum and Geosystems Engineering annual report, 1990--1991 academic year. Office of Scientific and Technical Information (OSTI), December 1991. http://dx.doi.org/10.2172/10184021.

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PR-312-10202-E01 Characterization of Natural Gas Pneumatic Device Types Vent Rates. Chantilly, Virginia: Pipeline Research Council International, Inc. (PRCI), February 2014. http://dx.doi.org/10.55274/r0010554.

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For the onshore natural gas transmission compression and storage segments, natural gas pneumatic device venting is included as one of reportable sources required under Subpart W "Petroleum and Natural Gas Systems" of the GHG Mandatory Reporting Rule (MRR). In the natural gas transmission and storage industry, pneumatic devices are used to control process conditions such as temperature, pressure, flow and liquid level. A count and categorization into continuous high-, intermittent-, and continuous low-bleed pneumatic devices is required to calculate GHG emissions from pneumatic controllers. EPA has not specified a method to classify each pneumatic device, and Subpart W instructs reporters to "determine the type of pneumatic device using engineering estimates based on best available information." Thus, companies must determine which category is appropriate for each pneumatic device, and the device count must be updated annually. This report includes an introduction and background on the GHG Mandatory Reporting Rule (MRR) and pneumatic device source in Section 1. Section 2 provides a discussion of the project objectives and a discussion of the efforts to compile pneumatic device information. Section 3 provides a comparison of the default MRR GRI-EPA Tier 2 pneumatic device emission factors to other published rates. Section 4 explores pneumatic device types used in natural gas transmission and storage. Section 5 provides a summary of the Subpart W pneumatic device emission calculation methodology. Section 6 provides a summary of vendor survey results including the Excel calculation and device lookup tools. Sections 7 and 8 provide initial conclusions from the vendor survey and nomenclature and categorization issues, respectively. Section 8 also includes a discussion of factors that complicate classification and options to consider when resolving this for Subpart W reporting - and new complication associated with parallel definitions for Subpart OOOO control rule. The document includes a macro enabled spreadsheet that can be used to estimate emission rates from pneumatic controllers.

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