Thesis (M.S.)--Oregon State University, 2007. / Printout. Includes bibliographical references (leaves 78-79). Also available on the World Wide Web.

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Produced Water (PW) is the largest volume of waste that is normally generated during oil and gas production. It has large amounts of contaminants that can cause negative environmental and economic impacts. The management method for PW relies highly on types and concentrations of these contaminants, which are field dependent and can vary from one oil field to another. Produced water can be converted to fresh water if these contaminants are removed or reduced to the acceptable drinking water quality level. In addition, increasing oil production rate and reducing amounts of discharged harmful contaminants can be achieved by removing dissolved hydrocarbons from PW. In order to identify the types of these contaminants, effective tools and methods should be used. Six Sigma, which uses the DMAIC (Define- MeasureAnalyze- Improve- Control) problem-solving approach is one of the most effective tools to identify the root causes of having high percentages of contaminants in produced water. The methodology also helped develop a new policy change for implementing a way by which this treated water may be used. Six Sigma has not been widely implemented in oil and gas industries. This research adopted the Six Sigma methodology through a case study, related to the southern Iraqi oil fields, to investigate different ways by which produced water can be treated. Research results showed that the enormous amount of contaminated PW could be treated by using membrane filtration technology. In addition, a Multi Criteria Decision Making (MCDM) framework is developed and that could be used as an effective tool for decision makers. The developed framework could be used within manufacturing industries, services, educational systems, governmental organizations, and others. iv This work is dedicated to my scholarship providers and supporters wit

Orientador: Denis Jose Schiozer / Dissertação (mestrado) - Universidade Estadual de Campinas, Faculdade de Engenharia Mecanica e Instituto de Geociencias / Made available in DSpace on 2018-08-04T17:38:31Z (GMT). No. of bitstreams: 1 Magalhaes_TassoCordeiroBenevidesde_M.pdf: 3378169 bytes, checksum: 1fce57c554e09b19fe2b8796625d7f8b (MD5) Previous issue date: 2005 / Resumo: Estratégias de produção para campos petrolíferos são escolhidas com o objetivo de obter o melhor desempenho possível dos reservatórios, considerando restrições físicas, operacionais e econômicas. Em vários trabalhos publicados sobre otimização das estratégias de produção considera-se apenas o reservatório, simplificando o processo de definição por não considerar as restrições operacionais das facilidades de produção. Entretanto, as restrições da unidade de processamento e dos equipamentos necessários para o escoamento do petróleo, não só influenciam a produtividade do reservatório e o retorno financeiro do empreendimento, como também podem causar impacto significativo na definição da estratégia de drenagem, influenciando a quantidade e localização de poços produtores e injetores e no gerenciamento das condições de operação. No presente trabalho, duas restrições operacionais são analisadas: a limitação da capacidade de tratamento de líquidos da unidade de produção e a quantidade gás no sistema de elevação, gas-lift. Foram otimizadas estratégias de produção com e sem tais restrições para alguns casos e várias diferenças puderam ser observadas nos valores de indicadores técnicos e financeiros, como valor presente líquido, produção e injeção de fluidos e a quantidade e posicionamento de poços produtores e injetores. Foi possível demonstrar a influência das restrições operacionais e que se as mesmas não forem incluídas no processo de otimização antes da definição da quantidade e posição dos poços, o desempenho do campo pode ser prejudicado / Abstract: Production strategies for petroleum fields are chosen with the objective of achieving the best possible performance of the reservoir, considering physical, operational and economical constraints. In many published papers regarding production strategy optimization, only the reservoir is considered, simplifying the analysis process by not considering the operational constraints of production facilities. However, the restrictions of a production unit and the necessary equipments to guarantee the flow of petroleum not only have influence on the reservoir production and on the enterprise profits, but can also cause significant impact on the definition of the drainage strategy, influencing the number and location of producer and injector wells and the operational conditions management. In this work, two operational constraints are analyzed: the limitation of the capacity for liquid treatment and the amount of available gas for gas-lift operation. Production strategies were optimized with and without these restrictions for some case-studies and many differences were noted in the value of technical and financial indicators, such as the net present value, the production and injection of fluids and the number and location of producer and injector wells. It was possible to demonstrate the influence of operational constraints and how their exclusion from the optimization process, before definition of the number and location of wells, can lead to a wrong assessment of the field performance / Mestrado / Reservatórios e Gestão / Mestre em Ciências e Engenharia de Petróleo

This study analyses the impact of oil-related developments on output, incomes and employment in Shetland. An Input-Output approach is adopted based on a Shetland transactions table constructed by the author. Using this, the pre-oil Shetland economy is analysed as base for assessing oil impact. Three major oil activities are identified and their local effects estimated: Supply Bases, the Sullom Voe Tanker Terminal, and Oil-related Construction. Estimates of the impact of these on local activity are given in aggregate and on an individual industry basis. Appropriate oil sector 'multipliers' are derived. Attempts are made to modify the basic estimates by allowing for 'negative multiplier' effects, induced investment and other elements of impact excluded in the basic model. Finally, the possibility of oil-induced changes in local technology is considered and its implications for the preceding impact estimates discussed. In the conclusions the results of the previous analysis are drawn together and some policy implications suggested by them are considered briefly.

Thesis is submitted in partial fulfilment for the degree of Master of Science in Development Planning to the Faculty of Engineering and the Built Environment, School of Architecture and Planning at the University of the Witwatersrand, Johannesburg, 2016 / Nigeria has earned huge revenues from the exploitation of oil resources in the Niger Delta since the discovery of oil in 1956. These huge economic gains have however, not been translated into sustainable growth and development. The Niger Delta is characterized by poverty and squalor which has been attributed to environmental degradation from the activities of oil exploitation by the Nigerian government and multi-national companies in the area and also poor governance. This study adopts an exploratory case study method to explores the interrelationship between Oil Exploitation, Environmental Impacts and Conflicts in the Niger Delta and tries to answer the question what is the nature of and inter-relationships between conflicts associated with oil exploitation in the Niger Delta Area? The Niger Delta area has experienced a lot of oil related conflicts over the decades, which have manifested in the form of peaceful protests, violence, combat with Nigerian military forces, rise of youth militia groups, illegal oil markets, vandalism of oil pipelines, hijacking of offshore and onshore oil vessels, hostage taking, kidnapping of expatriates and oil company workers in the region. Conflicts have also taken the form of inter-communal conflicts, intra-communal conflicts, inter-state conflicts and conflicts between the Nigerian Government Oil Companies and the affected communities. The root causes of conflicts include; the high dependence of the Niger government on oil revenue for economic growth, marginalisation and underdevelopment of the Niger Delta region, struggle for resource control and derivation formula, existing systems of neo-patrimonialism, corruption, land decrees and poor governance. The major findings include; the presence of crude oil in the Niger Delta is strongly linked to conflicts experienced in the area, rent seeking practices such as oil theft and bunkering, political thuggery, corruption and the struggle for economic and political power by political elites characterise the Niger Delta region. / XL2018

[pt] Em diversas etapas da cadeia de trabalho da Indústria de Óleo e Gás a atividade de Engenharia de Petróleo demanda processos que envolvem otimização. Mais especificamente, no gerenciamento de reservatórios, as metodologias para a tomada de decisão pelo uso de poços inteligentes envolvem processos de otimização. Nestes processos, normalmente, visa-se maximizar o VPL (Valor Presente Líquido), que é calculado através das curvas de produção de óleo, gás e água fornecidas por um simulador de reservatório. Estas simulações demandam alto custo computacional, muitas vezes inviabilizando processos de otimização. Neste trabalho, empregam-se técnicas de inteligência computacional - modelos de redes neurais artificiais e neuro-fuzzy - para a construção de aproximadores de função para simulador de reservatórios com o objetivo de diminuir o custo computacional de um sistema de apoio à decisão para utilização ou não de poços inteligentes em reservatórios petrolíferos. Para reduzir o número de amostras necessárias para a construção dos modelos, utiliza-se também Projeto de Experimentos Fatoriais Fracionado. Os aproximadores de função foram testados em dois reservatórios petrolíferos: um reservatório sintético, muito sensível às mudanças no controle de poços inteligentes e outro com características reais. Os resultados encontrados indicam que estes aproximadores de reservatório conseguem bom desempenho na substituição do simulador no processo de otimização - devido aos baixos erros encontrados e à substancial diminuição do custo computacional. Além disto, os testes demonstraram que a substituição total do simulador pelo aproximador se revelou uma interessante estratégia para utilização do sistema de otimização, fornecendo ao especialista uma rápida ferramenta de apoio à decisão. / [en] In many stages of the work chain of Oil & Gas Industry, activities of petroleum engineering demand processes that involve optimization. More specifically, in the reservoirs management, the methodologies for decision making by using intelligent wells involve optimization processes. In those processes, usually, the goal is to maximize the NVP (Net Present Value), which is calculated through the curves of oil, gas and water production, supplied by a reservoir simulator. Such simulations require high computational costs, therefore in many cases the optimization processes become unfeasible. Techniques of computational intelligence are applied in this study - artificial neural networks and neuro-fuzzy models - for building proxies for reservoirs simulators aiming at to reduce the computational cost in a decision support system for using, or not, intelligent wells within oil reservoirs. In order to reduce the number of samples needed for build the models, it was used the Fractional Factorial Design of Experiments. The proxies have been tested in two oil reservoirs: a synthetic one, very sensitive to changes in the control of intelligent wells and another one with real characteristics. The replacement of the simulator by the reservoir proxy, in an optimization process, indicates a good result in terms of performance - low errors and significantly reduced computational costs. Moreover, tests demonstrate that the total replacement of the simulator by the proxy, turned out to be an interesting strategy for using the optimization system, which provides to the users a very fast tool for decision support.

Thesis (M.C.P.)--Massachusetts Institute of Technology, Dept. of Urban Studies and Planning, 1982. / MICROFICHE COPY AVAILABLE IN ARCHIVES AND ROTCH / Bibliography: leaves 75-76. / by Oscar Salazar Rodriguez. / M.C.P.

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This work addresses the poroelastic effect on the processes involved in hydraulic fracturing and post-fracture production using a finite element based fully coupled poroelastic model which includes a triple system of wellbore-fracture-reservoir. A novel numerical procedure for modeling hydraulic fracture propagation in a poroelastic medium is introduced. The model directly takes into account the interaction of wellbore, hydraulic fracture and reservoir in a fully coupled manner. This allows realistic simulation of near fracture phenomena such as back stress and leak-off. In addition, fluid leak-off is numerically modeled based on the concept of fluid flow in porous media using a new technique for evaluating local pressure gradient. Besides, the model is capable of accommodating the zone of reduced pressure (including intermediate and fluid lag zones) at the fracture front so as to capture the behavior of fracture tip region more realistically. A fully coupled poroelastic model for gas reservoirs has been also developed using an innovative numerical technique. From the results of this study it has been found that fracture propagation pressure is higher in poroelastic media compared to that of elastic media. Also high formation permeability (in the direction normal to the hydraulic fracture) and large difference between minimum horizontal stress (in case of it being the smallest principal stress) and reservoir pressure reduce the rate of fracture growth. Besides, high pumping rate is more beneficial in elongating a hydraulic fracture whereas high viscous fracturing fluid is advantageous in widening a hydraulic fracture. It has been also shown that rock deformation, permeability anisotropy and modulus of elasticity can have a significant effect on fluid flow in a hydraulically fractured reservoir. Furthermore, it has been shown that long stress reversal time window and large size of stress reversal region can be caused by high initial pressure differential (i.e. the difference between flowing bottomhole pressure and reservoir pressure), low initial differential stress (i.e. the difference between maximum and minimum horizontal stresses) and low formation permeability in tight gas reservoirs. By taking advantage of production induced change in stress state of a reservoir, this study has also shown that a refracture treatment, if carried out in an optimal time window, can lead to higher economic gain. Besides, analysis of stress reversal region has depicted that a small region with high stress concentration in the vicinity of the wellbore could impede refracture from initiating at the desired place. Moreover, re-pressurization of the wellbore can result in further propagation of the initial fracture before initiation or during propagation of the secondary fracture.