Thesis (M.S.)--San Diego State University, 1991. / Includes bibliographical references (leaves 124-133).

Orientador: Antonio Carlos Bannwart / Dissertação (mestrado) - Universidade Estadual de Campinas, Faculdade de Engenharia Mecânica e Instituto de Geociências / Made available in DSpace on 2018-08-21T23:41:35Z (GMT). No. of bitstreams: 1 Bragantini_MauroFernando_M.pdf: 5693941 bytes, checksum: bef9d874ab134a24eff92a6991db0e51 (MD5) Previous issue date: 2012 / Resumo: As bombas centrífugas submersas (BCS) são largamente empregadas para elevação artificial de petróleo, sendo, na sua configuração básica, acionadas por motores elétricos. Os motores elétricos são o elo mais sensível deste equipamento, apresentando baixo MTBF (Mean Time Between Failure), ocasionando intervenções custosas para o seu reparo e/ou substituição nas plataformas off-shore de produção de petróleo. O acionamento da BCS por outro meio é uma alternativa para aumento deste MTBF e a utilização de uma turbina hidráulica como força motriz uma possibilidade já viabilizada tecnicamente. Os produtos existentes no mercado, neste arranjo, BCS+Turbina, são denominados de HSP (Hydraulic Submersible pump). Devido às características construtivas da BCS, múltiplos estágios em série, diâmetro externo reduzido e acoplamento direto com o acionador, o projeto da turbina deve ser alinhado com estes requisitos. Este trabalho investiga a definição da carga de certa BCS bombeando óleo, analisa os diferentes métodos de predição do comportamento desta mesma BCS funcionando como turbina como opção de acionamento, estabelece as condições de projeto deste arranjo, o constrói, o ensaia e compara os resultados com as metolodogias de predição pesquisadas / Abstract: Bore-hole electrical submersible pumps (ESP) are largely used as oil artificial lift alternative. Electrical motor is the most sensitive component of this equipment presenting low MTBF (Mean Time Between Failure) causing high cost operations to fit or replace it on oil production off-shore platforms. ESP driving by another mean is an alternative to increase MTBF and a hydraulic turbine as driver is a technical possibility already available. Market existing products on this arrangement are called HSP (Hydraulic Submersible pump). Due to ESP constructive characteristics like multiple stages, reduced bore-hole diameter and direct coupled to the driver the turbine design should meet these requirements. This work investigates certain SP (Submersible Pump) load when pumping oil and the different prediction methods of this same SP running as turbine as drive option, also establishes the design conditions of this arrangement, builds it, tests it and compares the results against the researched prediction methodologies / Mestrado / Explotação / Mestre em Ciências e Engenharia de Petróleo

The development and production of Canadian offshore petroleum deposits raises three key sets of issues of interest to economists. First are questions relating to the impact of royalties and taxes on producer decisions, and hence on the level and efficiency of resource taxation. Other issues concern the impacts on the overall economy during both the construction and production phases. A third set of issues relates to the distribution of powers and resource revenues between federal and provincial governments, including the links between provincial resource revenues and equalization payments. This thesis develops a numerically tractable economic model designed to examine these issues. At the model's core is a one-to-one relationship between development plans and production profiles. This property is exploited in simulating the behaviour of a price-taking, net-present-value-maximizing producer under conditions of certainty. The model is linked with a macroeconometric model of the Canadian economy to study the potential consequences of Hibernia, a petroleum deposit located in the Eastern Canadian offshore region. This deposit was chosen for analysis because its size, location and low costs (relative to current world oil prices) combine to raise all of the issues listed above. In most cases studied, producer responses to government policies result in the dissipation of less than five percent of the deposit's net present value to society. Although cases are identified where these responses have more serious consequences, the resulting dissipation of potential net benefits never exceeds 15 percent. The extension of specific forms of royalty and tax relief to the producer generally reduces the distortionary effects of government policies. The simulated exploitation of Hibernia induces small but sympathetic changes in most macroeconomic variables. The net crowding-out effects on other industries are shown to be relatively small, and to be more prevalent during the construction period. The results suggest that the larger share of the net benefits accruing to governments flows to the provincial treasury under three of the revenue-sharing systems modelled. However, Newfoundland and Labrador would lose a substantial portion of its Hibernia revenues under all of the equalization systems modelled. / Arts, Faculty of / Vancouver School of Economics / Graduate

published_or_final_version / Comparative Asian Studies / Master / Master of Arts

This dissertation presents results from a complex seismic study using Ocean Bot¬tom Seismometers (OBS) conducted at a site of deep sea gas hydrate occurrence. The site is located on the accretionary margin of the northern Cascadia subduction zone offshore Vancouver Island. Canada. The major objectives for this study were the construction of a 3-D velocity model around the Bullseye vent zone by the means of travel time inversion tomography and the analysis of the amplitude data for reflections from the water-sediment interface and the bottom simulating reflector (BSR). Secondary objectives included the integration of the results from this study with previous knowledge about the vent zone for further clarification of its structure and evolution. The OBS seismic data set consisted of 22 parallel lines at 200 in spacing with three perpendicular crossing lines recorded on five OBS stations. Multichannel and single channel conventional seismic data along these lines were also acquired. The OBS experiment geometry required corrections for the coordinates of sources and receivers initially obtained in the field. A new comprehensive source and receiver localization technique was developed for the case of stationary hydrophones and multiple seismic lines. The horizontal size of the created 3-D velocity model is 3 km x 2.7 km. The modelled volume is limited by the seafloor at the top and by the BSR at the bottom. The size of a grid cell is 50 m x 50 m x 20 m. The uncertainty for the velocity value of individual cells was as low as 20 m/s. although the resolution of the model was reduced by the sparse receiver geometry. The inversion results indicate a fairly uniform velocity field around and inside the vent zone. Velocities are nearly equal to values expected for sediments containing no hydrate, which supports the idea that the bulk concentrations of gas hydrates are low at the site. The largest velocity anomaly with an amplitude of +25 m/s is spatially associated with the limits of the blank zone. The anomaly suggests greater gas hydrate concentrations inside the vent zone than outside. Low vertical resolution of the model did not provide information on the depth distribution of the hydrate. However, the combination of the information from the velocity inversion with previous studies suggests that the zone of high hydrate concentration (15-20% of the pore space) associated with a hydrate lens, located at the top of the sediment section. The vent site is characterized by a negative anomaly of the seafloor reflection coefficient, outlined by a high amplitude rim. The low reflection coefficient is believed to be the result of the processes taking place above the hydrate lens, methane venting in particular. and the high amplitude rim to be the effect of carbonate formation. The seafloor reflection coefficient zonation appears to be correlated with the distribution of low magnetic susceptibility zone in the first 8 in of the sediment section. Both phenomena can be related to the distribution of upward fluid flow at the vent site. The cause of the blanking phenomena is likely different for different frequencies of the seismic signal. The blanking at high frequencies is an effect of near-surface disturbed sediments due to active venting and, possibly. free gas presence at the top of the vent zone. The blanking for the middle range of seismic frequencies is mostly the effect of reduced impedance contrast between the sediment layers inside the blank zone due to local presence of gas hydrates in small concentrations (2-3%). It is concluded that. the Bullseye vent zone, which shows very low activity presently, was probably much more active in the past (similar to a mud volcano). The past ac¬tivity may have led to the formation of the bathymetric expression of the vent site (a mound), together with the hydrate lens and authigenic carbonates.

This thesis explores the legal and political contexts in which offshore oil and gas (OOG) decisions in British Columbia's Queen Charlotte Basin (Basin) are being made and situates these decisions within Canada's integrated coastal and oceans management (ICOM) strategy. The geography, ecology and current ocean uses of the Basin are reviewed and environmental impacts of OOG considered. The federal-provincial jurisdictional and ownership complexities and issues of aboriginal rights and title are then reviewed. Canada's efforts to implement ICOM through the Oceans Act and subsequent policies are assessed. as compared to the U.S. model and in light of international principles. Core ICOM principles of sustainability, integration. precaution and transparency are specifically reviewed. While Canada's oceans strategy is consistent with internationally-accepted principles, it falls short of a true ICOM regime and is not sufficiently developed to resolve the OOG debate. Nonetheless, OOG decisions can and should be guided by its principles.

Thesis (M.Sc.)--Memorial University of Newfoundland, 2003. / Error in pagination: Appendix p. [241] is numbered 235. Bibliography: leaves 234-240. Also available online.

Orientador: Denis Jose Schiozer / Dissertação (mestrado) - Universidade Estadual de Campinas, Faculdade de Engenharia Mecanica, Instituto de Geociencias / Made available in DSpace on 2018-08-12T22:36:54Z (GMT). No. of bitstreams: 1 Costa_OdairJose_M.pdf: 3077427 bytes, checksum: 9a5e85d5b3ea4c69fdd9a468b62a50de (MD5) Previous issue date: 2008 / Resumo: A reinjeção de água produzida é um método muito utilizado para descarte de água e para suporte de pressão e energia do reservatório. Um problema comum da reinjeção é a perda de injetividade, que prejudica o processo e impede a operação em níveis ótimos de injeção. A perda de injetividade pode ser minimizada pela injeção de água com pressão acima da pressão de fratura do reservatório (IPF), que procura restaurar a capacidade de injeção. Para estudar este processo, um simulador geomecânico para modelagem da fratura é combinado com um simulador numérico de reservatórios para modelar e otimizar a condição de operação dos poços injetores. A fratura é representada por um poço horizontal virtual, de forma conjunta com formulações analíticas de declínio hiperbólico de permeabilidade, para representar o efeito do dano de formação. O objetivo do trabalho é estudar alguns casos para verificar em quais situações a IPF é conveniente. O modelo de simulação estudado foi um reservatório sintético com um arranjo de drenagem de cinco pontos invertido representando uma parte de um reservatório. Foram considerados três cenários, onde a variação foi o tipo de óleo empregado (leve, intermediário e pesado). Estes cenários foram elaborados com a finalidade de representar algumas possíveis situações que podem ocorrer em um campo real, onde a pressão de iniciação de fratura pode ser atingida pelo efeito da perda de injetividade ou devido às propriedades rocha-fluido. O desempenho da IPF foi avaliado utilizando o valor presente líquido (VPL) e produções acumuladas de óleo e água. Os resultados mostraram que o estudo da IPF pode ser considerado como parte de um processo de otimização de vazão de injeção, onde a fratura pode ou não ocorrer. Mostra-se que a IPF, em geral, antecipa a produção de óleo para os casos de viscosidade intermediária e alta, tornando o método bastante vantajoso, embora com maior produção de água. Já estudos com óleo leve indicam que a técnica só é interessante quando houver significativa perda de injetividade, onde a IPF serve como reparadora da injetividade / Abstract: Produced water re-injection is a valuable method of water disposal and pressure and energy support. A common water re-injection problem is the injectivity loss, which affects negatively the process and restrains optimal water injection rates. The injectivity loss can be minimized by water injection with fracture propagation pressure (IFPP), which aims to restore injection capacity. To study this process, a geo-mechanical simulator for fracture modeling combined with a commercial reservoir simulation package is used to model and to optimize the operation condition of water injection wells. The fracture is represented by a virtual horizontal well and analytical formulations of hyperbolic decline of permeability are used to represent the effect of formation damage. This work aims the study of some cases to verify in which situations the IFPP is convenient. The simulation model studied is a synthetic reservoir with a five-spot pattern, representing a region of a reservoir. Three scenarios are considered, with different oil types (light, intermediate and heavy). These scenarios are proposed to reproduce some possible situations, where fracture pressure can be reached by the effect of the injectivity loss or due to rock and fluid characteristics. The behavior of the IFPP is evaluated using the net present value (NPV) and cumulative oil and water productions. The results showed that the IFPP study can be considered as part of an optimization problem of injection flow, where the fracture may occur. It is shown that IFPP, in general, presents advantages for intermediate and high viscosity oil because it anticipates oil production. Studies with light oil indicate that the technique is only interesting when there is significant injectivity loss, where IFPP is desirable for injectivity restoration / Mestrado / Reservatórios e Gestão / Mestre em Ciências e Engenharia de Petróleo

Substantial amounts of methane are sequestered in naturally occurring ice-like formations known as gas hydrates. In particular, oceanic gas hydrates are globally distributed in complex heterogeneous ecosystems that typically occur at depths exceeding 300 m. Gas hydrates have received attention for their potential as an alternative energy resource, as marine geohazards, and their role in cycling of greenhouse gases. In addition, chemosynthetic communities often play a vital role in the cycling and sequestration of carbon emanating from cold hydrocarbon seeps surrounding hydrate sites. Research efforts are presently striving to better understand the significance and complexity of these ecosystems through the establishment of seafloor observatories capable of long-term monitoring with integrated sensor networks. In this thesis, infrared (IR) spectroscopy has been implemented for the investigation of molecular-specific signatures to monitor gas hydrate growth dynamics and evaluate carbonate minerals, which are intimately connected with complex chemosynthetic processes occurring in these harsh environments. The first fundamental principles and data evaluation strategies for monitoring and quantifying gas hydrate growth dynamics utilizing mid-infrared (MIR) fiber-optic evanescent field spectroscopy have been established by exploiting the state-responsive IR absorption behavior of water. This has been achieved by peak area evaluation of the O-H stretch, H-O-H bend, and libration modes and assessing peak shifts in the 3rd libration overtone and libration bands during the formation and dissociation of simple clathrate hydrates of methane, ethane, and propane formed from aqueous solution. Hydrate growth and monitoring was facilitated with a customized pressure cell enabling operation up to ~5.9 MPa with spectroscopic, temperature, pressure, and video monitoring capabilities. Furthermore, the initial feasibility for extending the developed IR spectroscopic hydrate monitoring strategies into oceanic gas hydrate ecosystems has been demonstrated through the evaluation of potential spectroscopic interferences from sediment matrices in samples collected from two hydrate sites in the Gulf of Mexico (GoM). With exception of the libration band, the primary IR absorption features of water are readily accessed within hydrated sediment samples. Additional consideration for potential long-term hydrate monitoring applications revealed that the collection of approx. 2 IR spectra per day should enable direct insight into the temporal dynamics of hydrates...

Orientador: Celso Kazuyuki Morooka / Dissertação (mestrado) - Universidade Estadual de Campinas, Faculdade de Engenharia Mecânica e Instituto de Geociências / Made available in DSpace on 2018-08-26T04:25:15Z (GMT). No. of bitstreams: 1 Goncalves_MaiaraMoreira_M.pdf: 2713085 bytes, checksum: 084d81696889df2f638780ba891370e3 (MD5) Previous issue date: 2014 / Resumo: O desenvolvimento de um sistema marítimo de produção de petróleo corresponde a um conjunto de equipamentos para viabilizar a extração de petróleo e gás, a partir de um reservatório de petróleo. Para uma melhor compreensão do processo, a definição deste sistema de produção pode ser dividida em fases. Fase I corresponde à seleção do número de poços e tipo do poço. Então, seguindo trabalhos anteriores (FRANCO, 2003), na Fase II, o arranjo de poços e a Unidade Estacionária de Produção (UEP) são selecionados. E, na Fase III, a alternativa para o armazenamento e escoamento de óleo e gás produzidos é escolhida. O presente trabalho tem como objetivo identificar os impactos ambientais associados com cada componente de um sistema marítimo de produção de óleo e gás, e quantificar cada um deles por meio de índices. É esperado que esta ferramenta irá apoiar os tomadores de decisão ao selecionarem o sistema que melhor se ajuste a um determinado campo marítimo de petróleo. A crescente necessidade de petróleo na matriz energética do Brasil, concomitante com a preocupação da sociedade em manter o meio ambiente limpo, torna a inclusão de um índice relacionado com o meio ambiente uma importante contribuição para melhorar o processo de seleção e decisão sobre o sistema marítimo de produção e sua inclusão, além dos índices técnicos e tecnológicos geralmente usados em tal processo. Particularmente, será fundamental para a produção de petróleo em condições adversas do cenário pré-sal, que está localizado em lâminas d¿água cada vez mais profundas. A metodologia proposta segue um procedimento semelhante à avaliação dos impactos ambientais através da utilização do Índice de Sensibilidade Ambiental (ISA) e do uso de matriz de impacto (NOAA, 1997; PATIN, 1999; MARIANO; LA ROVERE, 2006). Para a estimativa dos impactos ambientais, foi definido o ISA da área a ser desenvolvida, e foi construída uma matriz de impacto com base nas atividades envolvidas na instalação de plataforma, fase operacional e descomissionamento de uma UEP e os elementos do meio ambiente. Portanto, essa abordagem sistemática e estruturada permitiu incorporar ao processo de seleção do sistema marítimo de produção para um campo de óleo e gás, a seleção da melhor alternativa, que combina as melhores características técnicas e tecnológicas com os melhores aspectos do ambiente / Abstract: The development of an offshore petroleum production system corresponds to define a set of equipment to make possible oil and gas extraction from an underwater petroleum reservoir. To better comprehension of the process, definition of this production system can be divided into phases. Phase I corresponds to the selection of number of wells and type of the well. Then, following the previous work (FRANCO, 2003), in the Phase II, the layout arrangement of wells and the set of the stationary Floating Production Unit (FPU) are selected. And, in the Phase III, storage and offloading alternatives for the produced oil and gas are selected. The present paper aims to identify environmental impacts associated with the each component of an offshore system for oil and gas production, and quantify each of them through indexes. It is expected to support the decision makers to select the best fitted system for a given offshore petroleum field. The increasing needs of petroleum to fulfill the energy matrix demanded in Brazil, the growing concern of the society for keeping the environment clean and the inclusion of an index related to the environment besides the technical and technological indexes usually taken makes it an important contribution to improve the process for selection and decision about the offshore production system. Particularly, it will be fundamental in the adverse condition of the Pre-salt scenario of petroleum production, in ultra-deep water depth and oil and gas with more aggressive contaminants to the system. The proposed methodology follows a similar procedure for the assessment of environmental impacts through the use of environmental sensitivity index (ESI) and the use of impact matrix (NOAA, 1997; PATIN, 1999; MARIANO; LA ROVERE, 2006). For the estimation of environmental impacts, it was defined the ESI of the area to be developed, and it was constructed an impact matrix based on the activities involved in the installation of platform, operational phase and decommissioning of a FPU and the elements from environment. Therefore, this systematic and structured approach allowed incorporating to the process of selection of the offshore production system for an oil and gas field the selection of alternative which combines the best technical and technological characteristics with better aspects from the environment / Mestrado / Explotação / Mestra em Ciências e Engenharia de Petróleo