Submitted by Automa??o e Estat?stica (sst@bczm.ufrn.br) on 2016-06-06T21:01:05Z No. of bitstreams: 1 GabrielPabloNudelman_DISSERT.pdf: 4667154 bytes, checksum: 87376721e94f9b7485cbec0fb6ad20a8 (MD5) / Approved for entry into archive by Arlan Eloi Leite Silva (eloihistoriador@yahoo.com.br) on 2016-06-08T20:53:05Z (GMT) No. of bitstreams: 1 GabrielPabloNudelman_DISSERT.pdf: 4667154 bytes, checksum: 87376721e94f9b7485cbec0fb6ad20a8 (MD5) / Made available in DSpace on 2016-06-08T20:53:05Z (GMT). No. of bitstreams: 1 GabrielPabloNudelman_DISSERT.pdf: 4667154 bytes, checksum: 87376721e94f9b7485cbec0fb6ad20a8 (MD5) Previous issue date: 2015-09-29 / Nos ?ltimos dezesseis anos surgiu no Brasil um segmento de produtores independentes com foco de atua??o nas bacias terrestres e de ?guas rasas. Entre os desafios destas empresas se encontra o desenvolvimento de campos com projetos com um valor presente l?quido (VPL) baixo. O objetivo deste trabalho foi estudar a melhor op??o t?cnico-econ?mica de desenvolvimento de um campo de petr?leo no Nordeste Brasileiro aplicando a simula??o de reservat?rios. A partir de dados reais de geologia, reservat?rios e produ??o foi realizado o modelo geol?gico e de simula??o. Devido a n?o ter an?lise PVT, foram utilizados os dados do ensaio de destila??o denominado Pontos de Ebuli??o Verdadeiros (PEV) para criar um modelo de fluidos gerando as curvas PVT. Ap?s realizado o ajuste manual do hist?rico, foram simulados quatro cen?rios de desenvolvimento: a extrapola??o de produ??o sem novos investimentos, a convers?o de um po?o produtor para inje??o de g?s imisc?vel, a perfura??o de um po?o vertical e a perfura??o de um po?o horizontal. Como resultados, do ponto de vista financeiro, a inje??o de g?s foi a alternativa com menor valor agregado, podendo ser vi?vel caso haja restri??es ambientais ou regulat?rias de queima ou de ventila??o ao meio ambiente do g?s produzido do campo ou de campos vizinhos. O fator de recupera??o atingido com a perfura??o dos po?os vertical e horizontal ? similar, mas a perfura??o do po?o horizontal ? um projeto de acelera??o de produ??o, portanto a produ??o acumulada incremental atualizada com uma taxa m?nima de atratividade da empresa ? maior. A depender do pre?o do barril de petr?leo Brent e do custo de perfura??o esta op??o pode ser t?cnica e financeiramente vi?vel. / In the last 16 years emerged in Brazil a segment of independent producers with focus on onshore basins and shallow waters. Among the challenges of these companies is the development of fields with projects with a low net present value (NPV). The objective of this work was to study the technical-economical best option to develop an oil field in the Brazilian Northeast using reservoir simulation. Real geology, reservoir and production data was used to build the geological and simulation model. Due to not having PVT analysis, distillation method test data known as the true boiling points (TBP) were used to create a fluids model generating the PVT data. After execution of the history match, four development scenarios were simulated: the extrapolation of production without new investments, the conversion of a producing well for immiscible gas injection, the drilling of a vertical well and the drilling of a horizontal well. As a result, from the financial point of view, the gas injection is the alternative with lower added value, but it may be viable if there are environmental or regulatory restrictions to flaring or venting the produced gas into the atmosphere from this field or neighboring accumulations. The recovery factor achieved with the drilling of vertical and horizontal wells is similar, but the horizontal well is a project of production acceleration; therefore, the present incremental cumulative production with a minimum rate of company's attractiveness is higher. Depending on the crude oil Brent price and the drilling cost, this option can be technically and financially viable.