Dissertations / Theses on the topic 'Reservoir oil pressure'
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Xiao, Jinjiang. "Wellbore effects on pressure transient analysis /." Access abstract and link to full text, 1993. http://0-wwwlib.umi.com.library.utulsa.edu/dissertations/fullcit/9325433.
Full textOnur, Mustafa. "New well testing applications of the pressure derivative /." Access abstract and link to full text, 1989. http://0-wwwlib.umi.com.library.utulsa.edu/dissertations/fullcit/8917500.
Full textSerra, Kelsen Valente. "Well testing for solution gas drive reservoirs /." Access abstract and link to full text, 1988. http://0-wwwlib.umi.com.library.utulsa.edu/dissertations/fullcit/8811978.
Full textCamacho-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.
Full textVan, Ruth Peter John. "Overpressure in the Cooper and Carnarvon Basins, Australia /." Title page, abstract and table of contents only, 2003. http://web4.library.adelaide.edu.au/theses/09PH/09phv275.pdf.
Full textSathar, Shanvas. "Effect of oil emplacement on pressure solution in reservoir rocks : an experimental analogue study." Thesis, University of Liverpool, 2010. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.539512.
Full textBarreto, Filho Manuel de Almeida. "Estimation of average reservoir pressure and completion skin factor of wells that produce using sucker rod pumping /." Full text (PDF) from UMI/Dissertation Abstracts International, 2001. http://wwwlib.umi.com/cr/utexas/fullcit?p3008273.
Full textHossein, Zadeh Ahmad. "Optimization of Well Spacing and CO2 Miscible Flooding Startup Time in an Ultradeep, High Pressure Oil Reservoir." Thesis, Norges teknisk-naturvitenskapelige universitet, Institutt for petroleumsteknologi og anvendt geofysikk, 2014. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-27152.
Full textTeca, Dário Bokiló Machado. "Correction of the anisotropy in resistivity: application to pore pressure prediction." Master's thesis, Faculdade de Ciências e Tecnologia, 2014. http://hdl.handle.net/10362/13132.
Full textThis dissertation is based on a curricular training period done at company Total EP Angola between July and December 2013. The data presented relate to a real case study of an exploration block, which for reasons of confidentiality is designated by Block Michocho. The fluids pressure measurement in the geological formations can be inferred from the formation resistivity log. In not perpendicular wells to the layers, resistivity curves show higher values than the expected due to the anisotropic effect of the formation thus the inference of the pressure of fluids from resistivity logs can lead to unrealistic values. Most of the developments wells drilled on Block Michocho in Angola are highly deviated, if not sub-horizontal, in the reservoir section. The objective of this work is to correct the anisotropic effect of the resistivity of Block Michocho due to non-perpendicularity of the wells when intersect the geological formations. In this study, the correction of the resistivity is based on the formula proposed by Moran and Gianzero in 1979 and involves the dipping angle of the induction logging tool and the coefficient of anisotropy of the rock formation. Prior to application of this formula for the corrections of resistivity of the Block Michocho wells logs, a set of validation tests were made. Due to lack of data on development wells (highly inclined wells) the validation test was carried out in five exploration wells where resistivity is available in the two principal directions. It was assumed that the formula would be approved for resistivity corrections if the horizontal resistivity obtained by the formula had a good correspondence with the horizontal resistivity obtained by the induction logging tool. After this validation step, the coefficient of anisotropy to be used in the formula was calibrated as well as the correction of the curves of resistivity of the remaining development wells, those much more diverted regarding the rock layers. The corrected resistivity can be applied for pore pressure prediction in low permeability rock formations, in which the main objective is to identify regions where fluid pressure is higher than normal pressure, i.e. overpressure regions. For illustration purposes, a resistivity curve from an exploration well was chosen and the pressure of the fluids in low permeability rocks was computed by using the formula proposed by Eaton in 1975. With this well data, a potential overpressure region was identified and should be avoided in drilling activities.
Samadov, Hidayat. "Analyzing Reservoir Thermal Behavior By Using Thermal Simulation Model (sector Model In Stars)." Master's thesis, METU, 2011. http://etd.lib.metu.edu.tr/upload/12613336/index.pdf.
Full texthowever no significant changes were observed due to iteration number differences and refined grids. These latter cases showed clearly that variations of temperature don&rsquo
t occur only due to geothermal gradient, but also pressure and saturation changes. On the whole, BHT can be used to get data ranging from daily gas-oil ratios to interwell connection if analyzed correctly.
Hardy, Benjamin Arik. "A New Method for the Rapid Calculation of Finely-Gridded Reservoir Simulation Pressures." Diss., CLICK HERE for online access, 2005. http://contentdm.lib.byu.edu/ETD/image/etd1123.pdf.
Full textMourgues, Régis. "Surpressions de fluide et décollements : modélisations analogique et numérique /." Rennes : Éd. de Géosciences-Rennes, 2004. http://catalogue.bnf.fr/ark:/12148/cb39955647q.
Full textPraxedes, Tayllandya Suelly. "Efeito da perda de carga e calor no po?o injetor no processo de drenagem gravitacional assistido com vapor e solvente." Universidade Federal do Rio Grande do Norte, 2013. http://repositorio.ufrn.br:8080/jspui/handle/123456789/12991.
Full textConselho Nacional de Desenvolvimento Cient?fico e Tecnol?gico
Nowadays, most of the hydrocarbon reserves in the world are in the form of heavy oil, ultra - heavy or bitumen. For the extraction and production of this resource is required to implement new technologies. One of the promising processes for the recovery of this oil is the Expanding Solvent Steam Assisted Gravity Drainage (ES-SAGD) which uses two parallel horizontal wells, where the injection well is situated vertically above the production well. The completion of the process occurs upon injection of a hydrocarbon additive at low concentration in conjunction with steam. The steam adds heat to reduce the viscosity of the oil and solvent aids in reducing the interfacial tension between oil/ solvent. The main force acting in this process is the gravitational and the heat transfer takes place by conduction, convection and latent heat of steam. In this study was used the discretized wellbore model, where the well is discretized in the same way that the reservoir and each section of the well treated as a block of grid, with interblock connection with the reservoir. This study aims to analyze the influence of the pressure drop and heat along the injection well in the ES-SAGD process. The model used for the study is a homogeneous reservoir, semi synthetic with characteristics of the Brazilian Northeast and numerical simulations were performed using the STARS thermal simulator from CMG (Computer Modelling Group). The operational parameters analyzed were: percentage of solvent injected, the flow of steam injection, vertical distance between the wells and steam quality. All of them were significant in oil recovery factor positively influencing this. The results showed that, for all cases analyzed, the model considers the pressure drop has cumulative production of oil below its respective model that disregards such loss. This difference is more pronounced the lower the value of the flow of steam injection
Atualmente, a maior parte das reservas de hidrocarbonetos no mundo se encontram na forma de ?leo pesado, ultra-pesado ou betume. Para a extra??o e produ??o desse recurso ? necess?ria a implanta??o de novas tecnologias. Um dos processos promissores para a recupera??o desse ?leo ? a drenagem gravitacional assistida com vapor e solvente (ESSAGD) que utiliza dois po?os horizontais paralelos, onde o injetor ? disposto acima do produtor. A realiza??o do processo se d? mediante a inje??o de um aditivo de hidrocarboneto em baixa concentra??o em conjunto com vapor. O vapor contribui com calor para redu??o da viscosidade do ?leo e o solvente ajuda na miscibilidade, reduzindo a tens?o interfacial entre ?leo/solvente. A principal for?a atuante neste processo ? a gravitacional e a transfer?ncia de calor ocorre por meio da condu??o, convec??o e pelo calor latente do vapor. Neste estudo foi utilizado o modelo discretizado, onde o po?o ? discretizado da mesma forma que o reservat?rio, sendo cada se??o do po?o tratada como um bloco da grade, com conex?o interblocos com o reservat?rio. O presente trabalho tem como objetivo analisar a influ?ncia da perda de carga e calor ao longo do po?o injetor no processo ES-SAGD. O modelo utilizado para estudo trata-se de um reservat?rio homog?neo, semissint?tico com caracter?sticas do Nordeste Brasileiro e as simula??es num?ricas foram realizadas atrav?s do simulador t?rmico STARS da CMG (Computer Modelling Group). Os par?metros operacionais analisados foram: porcentagem de solvente injetado, vaz?o de inje??o de vapor, dist?ncia vertical entre os po?os e qualidade de vapor. Todos eles foram significativos no Fator de Recupera??o de ?leo. Os resultados demonstraram que, para todos os casos analisados, o modelo que considera a perda de carga apresenta produ??o acumulada de ?leo inferior ao seu respectivo modelo que desconsidera tal perda. Essa diferen?a ? mais acentuada quanto menor o valor da vaz?o de inje??o de vapor
Tingas, John. "Numerical simulation of air injection processes in high pressure light & medium oil reservoirs." Thesis, University of Bath, 2000. https://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.343763.
Full textAbdelmottleb, Hashem A. "Partially scaled SAGD-type experiments of heavy oil reservoirs in a low-pressure physical model." Thesis, National Library of Canada = Bibliothèque nationale du Canada, 2000. http://www.collectionscanada.ca/obj/s4/f2/dsk1/tape4/PQDD_0008/MQ60086.pdf.
Full textZhang, Kaiyi. "CO2 Minimum Miscibility Pressure and Recovery Mechanisms in Heterogeneous Low Permeability Reservoirs." Thesis, Virginia Tech, 2019. http://hdl.handle.net/10919/93728.
Full textMaster of Science
The new technologies to recover unconventional resources in oil and gas industry, such as fracturing and horizontal drilling, boosted the production of shale gas and tight oil in 21st century and contributed to the North America oil and gas production. Although the new technologies and strong demand spiked the production of tight oil resources, there are still unknowns of oil and gas flow mechanisms in tight rock reservoirs. As we know, the oil and gas resources are stored in the pores of reservoir formation rock. During production process, the oil and gas are pushed into production wells by formation pressure. However, the pore radius of shale rock is extremely small (around nanometers), which reduces the flow rate of oil and gas and raises capillary pressure in pores. The high capillary pressure will alter the oil and gas phase behavior and it may influence the value of minimum miscibility pressure (MMP), which is an important design parameter for CO2 injection (an important technology to raise production). To investigate this influence, we changed classical model with considering capillary pressure and this modified model is implemented in different methods to calculate MMP. The results show that CO2 -MMP in shale reservoirs are affected by capillary pressure and the results from different methods match well. Moreover, in tight rock reservoirs, the heterogeneous pore size distribution, such as fractures in reservoirs, may affect the flow of oil and gas and MMP value. So, this work also investigates the effect of pore size heterogeneity on oil and gas flow mechanisms. According to the simulation results, compositional gradient forms in heterogeneous nanopores of tight reservoirs and this gradient will cause diffusion which will dominate the other fluid flow mechanisms. Therefore, we always need to consider molecular diffusion in the simulation model for shale reservoirs.
Catonho, Humberto Sampaio. "Estudo do processo de combust?o in-situ em reservat?rios maduros de ?leos m?dios e leves (high pressure air injection)." Universidade Federal do Rio Grande do Norte, 2013. http://repositorio.ufrn.br:8080/jspui/handle/123456789/12989.
Full textNearly 3 x 1011 m3 of medium and light oils will remain in reservoirs worldwide after conventional recovery methods have been exhausted and much of this volume would be recovered by Enhanced Oil Recovery (EOR) methods. The in-situ combustion (ISC) is an EOR method in which an oxygen-containing gas is injected into a reservoir where it reacts with the crude oil to create a high-temperature combustion front that is propagated through the reservoir. The High Pressure Air Injection (HPAI) method is a particular denomination of the air injection process applied in light oil reservoirs, for which the combustion reactions are dominant between 150 and 300?C and the generation of flue gas is the main factor to the oil displacement. A simulation model of a homogeneous reservoir was built to study, which was initially undergone to primary production, for 3 years, next by a waterflooding process for 21 more years. At this point, with the mature condition established into the reservoir, three variations of this model were selected, according to the recovery factors (RF) reached, for study the in-situ combustion (HPAI) technique. Next to this, a sensitivity analysis on the RF of characteristic operational parameters of the method was carried out: air injection rate per well, oxygen concentration into the injected gas, patterns of air injection and wells perforations configuration. This analysis, for 10 more years of production time, was performed with assistance of the central composite design. The reservoir behavior and the impacts of chemical reactions parameters and of reservoir particularities on the RF were also evaluated. An economic analysis and a study to maximize the RF of the process were also carried out. The simulation runs were performed in the simulator of thermal processes in reservoirs STARS (Steam, Thermal, and Advanced Processes Reservoir Simulator) from CMG (Computer Modelling Group). The results showed the incremental RF were small and the net present value (NPV) is affected by high initial investments to compress the air. It was noticed that the adoption of high oxygen concentration into the injected gas and of the five spot pattern tends to improve the RF, and the wells perforations configuration has more influence with the increase of the oil thickness. Simulated cases relating to the reservoir particularities showed that smaller residual oil saturations to gas lead to greater RF and the presence of heterogeneities results in important variations on the RF and on the production curves
Aproximadamente 3 x 1011 m3 de ?leos m?dios e leves restar?o nos reservat?rios ao redor do mundo ap?s a aplica??o dos m?todos convencionais de recupera??o e grande parte desse volume seria recuper?vel com o uso de m?todos especiais. A combust?o in-situ (CIS) ? um m?todo de recupera??o avan?ada de petr?leo no qual um g?s que cont?m oxig?nio ? injetado no reservat?rio onde reage com o ?leo cru para criar uma frente de combust?o de alta temperatura que se propaga pelo reservat?rio. O m?todo HPAI (High Pressure Air Injection) ? uma denomina??o particular do processo de inje??o de ar aplicado em reservat?rios de ?leos leves, onde as rea??es de combust?o s?o dominantes entre 150 e 300?C e a gera??o de flue gas ? o principal fator de deslocamento do ?leo. Um modelo de simula??o de fluxo de um reservat?rio homog?neo foi constru?do para o estudo, o qual foi inicialmente submetido ? produ??o prim?ria, por 3 anos, e em seguida, ao processo de inje??o de ?gua por mais 21 anos. Nesse ponto, com a condi??o madura estabelecida no reservat?rio, foram selecionadas tr?s varia??es desse modelo, de acordo com o fator de recupera??o (FR) obtido, para o estudo da t?cnica de combust?o in-situ (HPAI). Em seguida realizou-se uma an?lise de sensibilidade sobre o FR de par?metros operacionais pr?prios do m?todo: vaz?o de inje??o de ar por po?o, concentra??o de oxig?nio no g?s injetado, esquema de inje??o de ar e configura??o dos canhoneados dos po?os. Essa an?lise, para um per?odo adicional de at? 10 anos produ??o, foi efetuada com o aux?lio da t?cnica de planejamento composto central. O comportamento do reservat?rio e os impactos de par?metros envolvendo as rea??es qu?micas e de particularidades de reservat?rio sobre o FR tamb?m foram avaliados. Adicionalmente foram elaborados uma an?lise econ?mica e um estudo de maximiza??o do FR do processo. As simula??es foram realizadas com o simulador de processos t?rmicos em reservat?rios STARS (Steam, Thermal and Advanced Process Reservoir Simulation) da CMG (Computer Modelling Group). Os resultados mostraram que os FR incrementais foram baixos e que o valor presente l?quido (VPL) ? impactado negativamente pelos elevados investimentos iniciais para compress?o do ar. Observou-se que a ado??o de maiores concentra??es de oxig?nio no g?s injetado e do esquema de inje??o de ar tipo five spot tende a favorecer o FR, e que a configura??o dos canhoneados dos po?os apresenta influ?ncia crescente com o aumento da espessura porosa com ?leo do reservat?rio. Casos simulados referentes ?s particularidades de reservat?rio indicaram que menores satura??es residuais de ?leo ao g?s levam a FR maiores e que a exist?ncia de heterogeneidades resulta em varia??es consider?veis nos FR e nas curvas de produ??o
Du, Fengshuang. "Investigation of Nanopore Confinement Effects on Convective and Diffusive Multicomponent Multiphase Fluid Transport in Shale using In-House Simulation Models." Diss., Virginia Tech, 2020. http://hdl.handle.net/10919/100103.
Full textDoctor of Philosophy
Shale reservoir is one type of unconventional reservoir and it has extremely small pore size, low porosity, and ultra-low permeability. In tight shale reservoirs, the pore size is in nanometer scale and the oil-gas capillary pressure reaches hundreds of psi. In addition, the critical properties (such as critical pressure and critical temperature) of hydrocarbon components will be altered in those nano-sized pores. In this research, two in-house reservoir simulation models, i.e., a compositionally extended black-oil model and a fully composition model are developed to examine the nano-pore confinement effects on convective and diffusive multicomponent multiphase fluid transport. The large nano-confinement effects (large gas-oil capillary pressure and critical property shifts) on oil or gas production behaviors will be investigated. Meanwhile, the nano-confinement effects and rock intrinsic properties (porosity and tortuosity factor) on predicting effective diffusion coefficient are also studied.
Тарко, Я. Б. "Технології та технічні засоби інтенсифікації нафтогазовидобутку на основі термогідродинамічних методів впливу на привибійну зону пластів." Thesis, Івано-Франківський національний технічний університет нафти і газу, 2005. http://elar.nung.edu.ua/handle/123456789/4069.
Full textДиссертация посвящена исследованию гидродинамических и термохимических процессов, происходящих в скважине и призабойной зоне пласта и разработке новых, методов интенсификации нефтегазодобычи. С учетом результатов анализа и систематизации основных причин снижения продуктивности скважин, разработана математическая модель процесса кольматации призабойной зоны при первичном раскрытии пласта. Проанализированы и классифицированы основные гидродинамические методы воздействия на призабойную зону пластов. Предложены методики расчета восстановления забойного давления и его распределения в пласте во время цикличного депрессиснно-репрессионного воздействия с использованием методов последовательной смени стационарных состояний и суперпозиции, а также теории гармонических колебаний. Разработана обобщенная математическая модель процесса вытеснения жидкости из скважины сжатым газом, аэрированной жидкостью и водогазовыми подушками с учетом работы пласта в условиях неустановившейся фильтрации. Созданы новые гидроимпульсные технологии и технические средства, основанные на депрессионно-репрессионном и имплозионном воздействии на призабойную зону пластов, которые направлены на восстановление и увеличение проницаемости пластов, а при необходимости и ее снижение в высокопроводимых и обводненных интервалах. Проведены теоретические и экспериментальные исследования по изучению ряда химических реакций, предложены новые реагенты для экзотермических реакций, на основании которых разработаны новые технологии термохимических и термокислотных обработок призабойной зоны пласта с использованием мелкодисперсного магния и азотной кислоты, в том числе синтезированной из коррозионнонеактивных реагентов; гипохлорита натрия или калия и аммиака с последующим взаимодействием продукта этой реакций - гидразина - с перекисью водорода; солей гидразина или гидроксиламина и нитритами щелочных металлов или аммония. Указанные технологии позволяют получить значительно большее количество тепла по сравнению с известными способами, они более технологичны и эффективны. Разработаны новые технология закачки суспензий смеси разных дисперсных реагентов в пласт, технология и техническое средство направленного реагентного воздействия на выбранные пласты. Разработанные технологии и технические средства защищены 12 авторскими свидетельствами и патентами, 6 из которых внедрены в нефтегазодобывающих скважинах ОАО „Укрнефгь”. В результате промышленного внедрения доказана высокая технологическая эффективность новых технологий, которая выражается в получении значительных объемов дополнительно добытой нефти и газа, а также улучшении характера вытеснения и повышения текущего коэффициента нефтеотдачи. Защищаются 40 научных работ.
The dissertation is devoted to research of hydrodynamic and thermo-chemical processes that take place in the well and wellbore zone and to development of new methods for oil and gas recovery intensification. There have been developed mathematical models of wellbore zone mudding processes during initial reservoir drilling-in, bottom-hole pressure recovery and its distribution at the reservoir during cyclic depression-repression influence, fluid displacement from the well with compressed gas and water-gas cushions. There have been created new technologies and technical means for hydro-impulse influence on wellbore zone of the reservoirs. There have been done theoretical and experimental researches of some chemical reactions. New set of reagents and technologies of thermo-chemical and thermo-acid treatments of wellbore zone have been developed on their base. The developed technologies and technical means are protected with 12 author's certificate and patents, 6 of them are successfully introduced in oil and gas production wells. 40 scientific works are under defense.
Furui, Kenji Hill A. D. "A comprehensive skin factor model for well completions based on finite element simulations." 2004. http://repositories.lib.utexas.edu/bitstream/handle/2152/1993/furuik042.pdf.
Full textStrauss, Jonathan Patrick. "Numerical simulation of pressure response in partially completed oil wells." Thesis, 2002. http://hdl.handle.net/10413/3283.
Full textThesis (M.Sc.)-University of Natal, Pietermaritzburg, 2002.
Suri, Ajay. "Cleanup of internal filter cake during flowback." Thesis, 2005. http://hdl.handle.net/2152/2337.
Full textAghighi, Mohammad Ali Petroleum Engineering Faculty of Engineering UNSW. "Fully coupled fluid flow and geomechanics in the study of hydraulic fracturing and post-fracture production." 2007. http://handle.unsw.edu.au/1959.4/40621.
Full textVan, Ruth Peter John. "Overpressure in the Cooper and Carnarvon Basins, Australia / Peter John van Ruth." Thesis, 2003. http://hdl.handle.net/2440/22125.
Full textPhD (by publication).
Includes bibliographical references.
vii, 21, [49] leaves : ill. (some col.), maps, photos (some col.) ; 30 cm.
Title page, contents and abstract only. The complete thesis in print form is available from the University Library.
Thesis (Ph.D.)--University of Adelaide, Australian School of Petroleum (ASP), 2004
Furui, Kenji. "A comprehensive skin factor model for well completions based on finite element simulations." Thesis, 2004. http://hdl.handle.net/2152/1993.
Full textHamza, Syed Muhammad Farrukh. "Shear-enhanced permeability and poroelastic deformation in unconsolidated sands." Thesis, 2012. http://hdl.handle.net/2152/ETD-UT-2012-08-6353.
Full texttext
Lacayo, Ortiz Juan Manuel. "Pressure Normalization of Production Rates Improves Forecasting Results." Thesis, 2013. http://hdl.handle.net/1969.1/151370.
Full text