Made available in DSpace on 2014-12-17T15:01:13Z (GMT). No. of bitstreams: 1 ValdirCRN.pdf: 131656 bytes, checksum: 4153e21d4042d68f4cdd2a9f2c14b5e9 (MD5) Previous issue date: 2007-08-31 / Petroleum is a complex combination of various classes of hydrocarbons, with paraffinic, naphtenic and aromatic compounds being those more commonly found in its composition. The recent changes in the world scenario, the large reserves of heavy oils and also the lack of new discoveries of large petroleum fields are indications that, in the near future, the oil recovery by conventional methods will be limited. In order to increase the efficiency of the extraction process, enhanced recovery methods are cited in applications where conventional techniques have proven to be little effective. The injection of surfactant solutions as an enhanced recovery method is advantageous in that surfactants are able to reduce the interfacial tensions between water and oil, thus augmenting the displacement efficiency and, as a consequence, increasing the recovery factor. This work aims to investigate the effects of some parameters that influence the surfactant behavior in solution, namely the type of surfactant, the critical micelle concentration (CMC) and the surface and interface tensions between fluids. Seawater solutions containing the surfactants PAN, PHN and PJN have been prepared for presenting lower interfacial tensions with petroleum and higher stability under increasing temperature and salinity. They were examined in an experimental apparatus designed to assess the recovery factor. Botucatu (Brazil) sandstone plug samples were submitted to assay steps comprising saturation with seawater and petroleum, conventional recovery with seawater and enhanced recovery with surfactant solutions. The plugs had porosity between 29.6 and 32.0%, with average effective permeability to water of 83 mD. The PJN surfactant, at a concentration 1000% above CMC in water, had a higher recovery factor, causing the original oil in place to be recovered by an extra 20.97%, after conventional recovery with seawater / O petr?leo ? uma combina??o complexa de v?rias s?ries de hidrocarbonetos, sendo as mais comumente encontradas as parafinicas, naft?nicas e arom?ticas. As recentes mudan?as no cen?rio mundial, as grandes reservas de ?leos pesados, bem como a escassez de descobertas de grandes campos de petr?leo, indicam que em um futuro pr?ximo a recupera??o de ?leo por m?todos convencionais ser? limitada. Para aumentar a efici?ncia do processo de extra??o, faz-se uso dos m?todos avan?ados de recupera??o para agir nos pontos onde o processo convencional mostrou-se pouco eficiente. A inje??o de solu??o de tensoativo, como um m?todo avan?ado de recupera??o mostra-se vantajosa, pois os tensoativos t?m a finalidade de reduzir as tens?es interfaciais entre a ?gua e o ?leo, ampliando a efici?ncia de deslocamento e, conseq?entemente, aumentando o fator de recupera??o. Este trabalho se prop?s a estudar os efeitos dos par?metros que influenciam as solu??es de tensoativos, como: tipo de tensoativo, concentra??o micelar cr?tica e tens?o superficial e interfacial entre os fluidos. As solu??es com ?gua do mar dos tensoativos PAN, PHN e PJN, por apresentarem menores tens?es interfaciais com o petr?leo e maior estabilidade com o aumento da temperatura e salinidade, foram estudadas em um aparato experimental para avalia??o do fator de recupera??o. Os testemunhos de arenito Botucatu foram submetidos a etapas de satura??o com ?gua do mar e petr?leo, recupera??o convencional com ?gua do mar e recupera??o avan?ada com solu??es de tensoativos. Os testemunhos apresentaram porosidade entre 29,6 e 32,0%, com permeabilidade m?dia efetiva ? ?gua de 83 mD. O tensoativo PJN, com concentra??o de 1000% acima da CMC apresentou maior fator de recupera??o, aumentando em 20,97% a recupera??o do ?leo original in place ap?s a recupera??o convencional com ?gua do mar