Caracterização do sistema petrolífero das águas rasas na Bacia do Espírito Santos com a aplicação de técnicas geofísicas

Fundação de Amparo à Pesquisa do Estado de São Paulo (FAPESP)

Evolução tectonossedimentar dos principais reservatórios de hidrocarbonetos do Campo de Golfinho (Bacia do Espírito Santo)

The Golfinho Field is located in the offshore region of the Espírito Santo Basin. Its importance is linked to the current average production about 19,000 barrels of oil per day, in turbidite reservoirs , giving it the nineteenth placement among the largest oil fields producing of Brazil. By interpretation and correlation’s methods based on 2D seismic sections and geophysical well logs, the study of tectonic-sedimentary evolution of major Golfinho Field’s reservoirs, which are located in Maastrichtian , aims understand and characterize the geological model of the area for the purpose of identify the main structures and types of reservoirs, improving the geological understanding of the area and using this knowledge at similar sets, that may present exploratory success in similar cases. By structural contour maps and geological cross-sections generated since time-depth conversion , the results defined for the geological model of the area , two distinct tectonic styles: a distensinal tectonics style , characterized by grabens and horsts , which belongs to rift phase, and a salt tectonics style, characterized by salt domes , listric faults and folds rolllover folds type, which belongs to marine phase . The interpretation of seismic sections and subsequent analysis of the main deformations present in the Maastrichtian reservoirs rocks ( turbidites ) showed that the northern region of the field is the most affected by salt tectonics . As for reservoirs, it was concluded to be associated to tectonics formed by rollover folds type, being older than listric faults

Modeling and Identification of an Open-frame Underwater Vehicle: The Yaw Motion Dynamics

A semi-autonomous unmanned underwater vehicle (UUV), named LAURS, is being developed at the Laboratory of Sensors and Actuators at the University of Sao Paulo. The vehicle has been designed to provide inspection and intervention capabilities in specific missions of deep water oil fields. In this work, a method of modeling and identification of yaw motion dynamic system model of an open-frame underwater vehicle is presented. Using an on-board low cost magnetic compass sensor the method is based on the utilization of an uncoupled 1-DOF (degree of freedom) dynamic system equation and the application of the integral method which is the classical least squares algorithm applied to the integral form of the dynamic system equations. Experimental trials with the actual vehicle have been performed in a test tank and diving pool. During these experiments, thrusters responsible for yaw motion are driven by sinusoidal voltage signal profiles. An assessment of the feasibility of the method reveals that estimated dynamic system models are more reliable when considering slow and small sinusoidal voltage signal profiles, i.e. with larger periods and with relatively small amplitude and offset.

Integration of processes induced air flotation and photo-Fenton for treatment of residual waters contaminated with xylene

Produced water in oil fields is one of the main sources of wastewater generated in the industry. It contains several organic compounds, such as benzene, toluene, ethyl benzene and xylene (BTEX), whose disposal is regulated by law. The aim of this study is to investigate a treatment of produced water integrating two processes, i.e., induced air flotation (IAF) and photo-Fenton. The experiments were conducted in a column flotation and annular lamp reactor for flotation and photodegradation steps, respectively. The first order kinetic constant of IAF for the wastewater studied was determined to be 0.1765 min(-1) for the surfactant EO 7. Degradation efficiencies of organic loading were assessed using factorial planning. Statistical data analysis shows that H2O2 concentration is a determining factor in process efficiency. Degradations above 90% were reached in all cases after 90 min of reaction, attaining 100% mineralization in the optimized concentrations of Fenton reagents. Process integration was adequate with 100% organic load removal in 20 min. The results of the integration of the IAF with the photo-Fenton allowed to meet the effluent limits established by Brazilian legislation for disposal. (C) 2011 Elsevier B.V. All rights reserved.

Areal Geology of the Post-Paleozoic Surface of the Northwest Plains

Probably most of the area included in this report has been ex­amined to some extent by oil geologists, and most, if not all, of the important domes have been discovered and surveyed thoroughly. In parts of the area, the bedrock is covered by glacial drift or alluvium materi­al, but it is reasonable to believe that no new domal structure will be found. This means that surface examination alone will be insufficient in locating new oil fields, so future prospecting will be dependent, to a great extent, on studies of sub-surface stratigraphy.

The Amplifier - v. 2, no. 15

In this issue...Yellowstone, Butte, Montana, Shamrock Picnic grounds, Carroll College, Butte Copper Baseball League, Civic Center, Dean McAuliffe

(Table 2) Concentrations and composition of aliphatic hydrocarbons in bottom sediments of the Sakhalin shelf

Aliphatic and polycyclic aromatic hydrocarbons were examined in the surface layer of bottom sediments from the eastern part of the Sakhalin Island shelf (materials were sampled in summer 2002). Concentrations of hydrocarbons were determined to know changed since beginning of development of oil fields (compared with earlier years). According to distribution of markers in hydrocarbon compositions, bottom sediments are dominated by allochthonous (terrigenous) hydrocarbons that are the most stable compounds. Occurrence of transformed anthropogenic oil alkanes that have never been found before may be indicative of increasing pollution in the region.

Estudio y diseño de un régimen fiscal que optimice la inversión en exploración y producción de hidrocarburos

Los regímenes fiscales que se aplican a los contratos de exploración y desarrollo de petróleo y gas, entre los propietarios del recurso natural (generalmente el país soberano representado por su gobierno) y las compañías operadoras internacionales (COI) que aportan capital, experiencia y tecnología, no han sabido responder a la reciente escalada de los precios del crudo y han dado lugar a que los países productores no estén recibiendo la parte de renta correspondiente al incremento de precios. Esto ha provocado una ola de renegociaciones llegándose incluso a la imposición unilateral de nuevos términos por parte de algunos gobiernos entre los que destacan el caso de Venezuela y Argentina, por ser los más radicales. El objetivo del presente trabajo es el estudio y diseño de un régimen fiscal que, en las actuales condiciones del mercado, consiga que los gobiernos optimicen sus ingresos incentivando la inversión. Para ello se simulan los efectos de siete tipos diferentes de fiscalidades aplicadas a dos yacimientos de características muy distintas y se valoran los resultados. El modelo utilizado para la simulación es el modelo de escenarios, ampliamente utilizado tanto por la comunidad académica como por la industria para comparar el comportamiento de diferentes regímenes fiscales. Para decidir cuál de las fiscalidades estudiadas es la mejor se emplea un método optimización multicriterio. Los criterios que se han aplicado para valorar los resultados recogen la opinión de expertos de la industria sobre qué factores se consideran deseables en un contrato a la hora invertir. El resultado permite delinear las características de un marco fiscal ideal del tipo acuerdo de producción compartida, sin royalties, con un límite alto de recuperación de crudo coste que permita recobrar todos los costes operativos y una parte de los de capital en cualquier escenario de precios, un reparto de los beneficios en función de un indicador de rentabilidad como es la TIR, con un mecanismo de recuperación de costes adicional (uplift) que incentive la inversión y con disposiciones que premien la exploración y más la de alto riesgo como la amortización acelerada de los gastos de capital o una ampliación de la cláusula de ringfence. Un contrato con estas características permitirá al gobierno optimizar los ingresos obtenidos de sus reservas de petróleo y gas maximizando la producción al atraer inversión para la exploración y mejorar la recuperación alargando la vida del yacimiento. Además al reducir el riesgo percibido por el inversor que recupera sus costes, menor será la rentabilidad exigida al capital invertido y por tanto mayor la parte de esos ingresos que irá a parar al gobierno del país productor. ABSTRACT Fiscal systems used in petroleum arrangements between the owners of the resource (usually a sovereign country represented by its government) and the international operating company (IOC) that provides capital, knowhow and technology, have failed to allocate profits from the recent escalation of oil prices and have resulted in producing countries not receiving the right share of that increase. This has caused a wave of renegotiations and even in some cases, like Venezuela and Argentina, government unilaterally imposed new terms. This paper aims to outline desirable features of a petroleum fiscal system, under current market conditions, for governments to maximize their revenues while encouraging investment. Firstly the impact of seven different types of fiscal regimes is studied with a simulation for two separate oil fields using the scenario approach. The scenario approach has been frequently employed by academic and business researchers to compare the performance of diverse fiscal regimes. In order to decide which of the fiscal regimes’ performance is best we used a multi-objective optimization decision making approach to assess the results. The criteria applied gather the preferences of a panel of industry experts about the desirable features of a contract when making investment decisions. The results show the characteristics of an ideal fiscal framework that closely resembles a production sharing contract, with no royalty payment and a high cost recovery limit that allows the IOC to recover all operating expenses and a share of its capital costs under any price scenario, a profit oil sharing mechanism based on a profitability indicator such as the ROR, with an uplift that allows to recover an additional percentage of capital costs and provisions that promote exploration investment, specially high-risk exploration, such as accelerated depreciation for capital costs and a wide definition of the ringfence clause. A contract with these features will allow governments to optimize overall revenues from its petroleum resources maximizing production by promoting investment on exploration and extending oil fields life. Also by reducing the investor’s perception of risk it will reduce the minimum return to capital required by the IOC and therefore it will increase the government share of those revenues.

Estratégia de manutenção de equipamentos elétricos em unidades offshore de produção de petróleo e gás baseada na filosofia de operações integradas.

A função Manutenção é extremamente relevante para garantir o cumprimento do planejamento da produção de óleo e gás natural de uma unidade marítima de produção, pois impacta diretamente na eficácia do processo produtivo. Quando se trata de uma instalação offshore, a manutenção passa a ser ainda mais importante, pois falhas em equipamentos e sistemas industriais podem, além de causar perdas econômicas, causar graves acidentes às pessoas e ao meio ambiente. Gerir a manutenção de uma planta industrial flutuante, localizada a 300 quilômetros da costa, como no caso daquelas localizadas nos campos do pré-sal brasileiro, é uma tarefa que requer a aplicação das técnicas mais modernas de gerenciamento de manutenção e processos de trabalho ágeis e dinâmicos para garantir o suporte técnico adequado a partir de instalações localizadas em ambientes onshore. Neste contexto, esta tese tem como objetivo avaliar e propor uma metodologia para definição da estratégia de manutenção a ser implementada em novas unidades de produção de petróleo e gás natural destinadas a operar em ambiente offshore. Esta metodologia, pautada na manutenção centrada em confiabilidade, tem como objetivo garantir que a estratégia de manutenção, além de garantir a máxima disponibilidade e eficiência dos equipamentos e sistemas, também seja compatível com a filosofia das Operações Integradas, recentemente desenvolvida pela indústria norueguesa de exploração e produção de petróleo para otimizar a produção de seus campos que já estão em fase de amadurecimento. Dessa forma, este trabalho contribuirá para que, com base na metodologia proposta para definição da estratégia de manutenção, novas plataformas de petróleo e gás natural possam operar com ainda mais segurança e eficiência, garantindo o melhor aproveitamento possível das reservas de petróleo. Este trabalho inclui uma análise de custos simplificada para os estudos de caso propostos, não fazendo parte do escopo do trabalho uma análise de custos detalhada para toda instalação.

Natural resources on the Russian continental shelf: Foreign investors sought... on Russian terms. OSW Commentary No. 76, 2012-05-09

In recent weeks, Rosneft, a Russian state-owned oil company, has signed co-operation agreements with three Western corporations: America’s ExxonMobil, Italy’s Eni, and Norway’s Statoil. In exchange for access to Russian oil fields on the continental shelf as minority shareholders, these Western investors will finance and carry out exploration there. They will also offer to Rosnieft technology transfer, staff exchange and the purchase of shares in their assets outside Russia (for example in the North Sea or in South America). Rosneft’s deals with Western energy companies prove that the Russian government is resuming the policy of a controlled opening-up of the Russian energy sectors to foreign investors which it initiated in 2006. So far, investors have been given access to the Russian electric energy sector and some onshore gas fields. The agreements which have been signed so far also allow them to work on the Russian continental shelf. This process is being closely supervised by the Russian government, which has enabled the Kremlin to maintain full control of this sector. The primary goal of this policy is to attract modern technologies and capital to Russia and to gain access to foreign assets since this will help Russian corporations to reinforce their positions in international markets. The signing of the above agreements does not guarantee that production will commence. These are a high-risk projects. It remains uncertain whether crude can be extracted from those fields and whether its development will be cost-effective. According to estimates, the Russian Arctic shelf holds approximately 113 billion tonnes of hydrocarbons. The development of these fields, including building any necessary infrastructure, may consume over US$500 billion within 30 years. Furthermore, the legal regulations currently in force in Russia do not guarantee that foreign investors will have a share in the output from these fields. Without foreign support, Russian companies are unlikely to cope with such technologically complicated and extremely expensive investments. In the most optimistic scenario, the oil production in the Russian Arctic may commence in fifteen to twenty years at the earliest.

Electrokinetics.

Mode of access: Internet.

Operation of electrified and automatic leases.

"A companion to Basic electricity for the petroleum industry."

Casing information.

Mode of access: Internet.

Statistics of petroleum exploration in the Caribbean, Latin America, Western Europe, the Middle East, Africa, non-communist Asia, and the southwestern Pacific /

Mode of access: Internet.