Submitted by Automa??o e Estat?stica (sst@bczm.ufrn.br) on 2015-11-12T14:48:35Z No. of bitstreams: 1 MariaDoSocorroBezerraDaSilva_DISSERT.pdf: 8242612 bytes, checksum: 0bf088500a19fde1a0ca76c1dbc40bd5 (MD5) / Approved for entry into archive by Elisangela Moura (lilaalves@gmail.com) on 2015-11-16T14:22:56Z (GMT) No. of bitstreams: 1 MariaDoSocorroBezerraDaSilva_DISSERT.pdf: 8242612 bytes, checksum: 0bf088500a19fde1a0ca76c1dbc40bd5 (MD5) / Made available in DSpace on 2015-11-16T14:22:56Z (GMT). No. of bitstreams: 1 MariaDoSocorroBezerraDaSilva_DISSERT.pdf: 8242612 bytes, checksum: 0bf088500a19fde1a0ca76c1dbc40bd5 (MD5) Previous issue date: 2014-02-13 / A explora??o e a produ??o de hidrocarbonetos exigem metodologias muito avan?adas para se conseguir trabalhar em condi??es cada vez mais adversas. Dentro destas novas metodologias de extra??o de petr?leo surge ? inje??o de solu??es polim?ricas, que torna-se eficiente no controle da mobilidade do fluido deslocante (?gua), e sob condi??es favor?veis, implica na antecipa??o da recupera??o de ?leo e, em alguns casos, fatores de recupera??o maiores. Este m?todo consiste em adicionar pol?meros ? ?gua de inje??o para aumentar sua viscosidade, fazendo com que a ?gua se difunda mais no meio poroso e aumentando a efici?ncia de varrido no reservat?rio. Neste trabalho, estuda-se atrav?s de simula??o num?rica, a aplica??o da inje??o de solu??o polim?rica em um reservat?rio homog?neo, semissint?tico com caracter?sticas do Nordeste Brasileiro, as simula??es num?ricas foram realizadas atrav?s do simulador t?rmico STARS da CMG (Computer Modelling Group). O trabalho teve como objetivo analisar a influ?ncia de alguns par?metros de reservat?rio sobre o comportamento de produ??o do ?leo, tendo como resposta a produ??o acumulada. As simula??es da inje??o de solu??o polim?rica, al?m da simula??o da inje??o de ?gua, consistiram em diversas etapas de an?lise de sensibilidade de par?metros de reservat?rio e operacionais. Foram realizadas simula??es para analisar a influ?ncia da inje??o de ?gua, solu??o polim?rica e inje??o alternada de bancos de ?gua e de solu??o polim?rica, comparando os resultados para cada condi??o simulada. As principais vari?veis avaliadas foram: viscosidade do ?leo, porcentagem de pol?mero injetado, viscosidade do pol?mero e vaz?o de inje??o de ?gua. A avalia??o da influ?ncia das vari?veis consistiu de um planejamento experimental completo seguido de uma an?lise por Diagrama de Pareto com o objetivo de apontar quais as vari?veis seriam mais influentes sobre a resposta representada pela produ??o acumulada do ?leo. Encontrou-se que todas as vari?veis influenciaram significativamente na recupera??o de ?leo e que a inje??o de solu??o polim?rica de forma cont?nua se mostrou mais eficiente para a produ??o acumulada quando comparada a recupera??o do ?leo por inje??o cont?nua de ?gua. A recupera??o prim?ria apresentou baixos n?veis de produ??o de ?leo, a inje??o de ?gua melhora significativamente a produ??o de ?leo no reservat?rio, mas a inje??o de solu??o polim?rica surge como uma nova metodologia para o incremento da produ??o de ?leo, aumento da vida ?til do po?o e poss?vel diminui??o de ?gua produzida. / Developing an efficient methodology for oil recovery is extremely important . Within the range of enh anced oil recovery, known as EOR, the injection of polymer solutions becomes effective in controlling the mobility of displacing fluid . This method consists of adding polymers to the injection water to increase its viscosity, so that more water diffuses in to the porous medium and increasing the sweep efficiency in the reservoir. This work is studied by numerical simulation , application of the injection polymer solution in a homogeneous reservoir , semisynthetic with similar characteristics to the reservoirs of the Brazilian Northeast , numerical simulations were performed using thermal simulator STARS from CMG (Computer Modelling Group ). The study aimed to analyze the influence of some parameters on the behavior of reservoir oil production, with the response to cumulative production. Simulations were performed to analyze the influence of water injection, polymer solution and alternating injection of water banks and polymer solution, comparing the results for each simulated condition. The primary outcomes were: oil viscosity, percentage of injected polymer, polymer viscosity and flow rate of water injection. The evaluation of the influence of variables consisted of a complete experimental design followed a Pareto analysis for the purpose of pointing out which va riables would be most influential on the response represented b y the cumulative oil production . It was found that all variables significantly influenced the recovery of oil and the injection of polymer solution on an ongoing basis is more efficient for the cumulative production compared to oil recovery by continuous water injection. The primary recovery show ed low levels of oil production , water injection significantly improves the pro duction of oil in the reservoir , but the injection of polymer solution em erges as a new methodology to increase the production of oil, increasing the life of the well and possible reduction of water produced.

Made available in DSpace on 2014-12-17T14:08:49Z (GMT). No. of bitstreams: 1 CindyPAR_DISSERT.pdf: 3888295 bytes, checksum: 74ba5d896661a5a41c98018b93246cd9 (MD5) Previous issue date: 2012-02-17 / Conselho Nacional de Desenvolvimento Cient?fico e Tecnol?gico / Oil recovery using waterflooding has been until now the worldwide most applied method, specially for light oil recovery, its success is mainly because of the low costs involved and the facilities of the injection process. The Toe- To-Heel Waterflooding TTHWTM method uses a well pattern of vertical injector wells completed at the bottom of the reservoir and horizontal producer wells completed at the top of it. The main producing mechanism is gravitational segregation in short distance. This method has been studied since the early 90?s and it had been applied in Canada with positive results for light heavy oils, nevertheless it hasn?t been used in Brazil yet. In order to verify the applicability of the process in Brazil, a simulation study for light oil was performed using Brazilian northwest reservoirs characteristics. The simulations were fulfilled using the STARS module of the Computer Modelling Group Software, used to perform improved oil recovery studies. The results obtained in this research showed that the TTHWTM well pattern presented a light improvement in terms of recovery factor when compared to the conventional 5- Spot pattern, however, it showed lower results in the economic evaluation / A recupera??o de ?leo com inje??o de ?gua tem sido at? agora o m?todo mais aplicado no mundo inteiro, principalmente para a recupera??o de ?leos leves; o sucesso deve-se aos baixos custos envolvidos e a facilidade de inje??o. O m?todo Toe-to-Heel Waterflooding TTHWTM utiliza uma configura??o de po?os injetores verticais completados no fundo do reservat?rio e po?os produtores horizontais completados no topo. O mecanismo de produ??o principal ? a segrega??o gravitacional em dist?ncias curtas. Este m?todo tem sido estudado desde o in?cio dos anos 90 e tem sido aplicado no Canad? com resultados positivos para ?leos levemente pesados, no entanto o m?todo ainda n?o tem sido utilizado no Brasil. Para verificar a aplicabilidade do processo no Brasil foi realizado um estudo de simula??o em reservat?rios de ?leo leve com caracter?sticas do Nordeste Brasileiro. O objetivo da pesquisa foi analisar quais os fatores operacionais que podem influenciar no processo. As simula??es foram realizadas utilizando o m?dulo STARS da Computer Modelling Group , com o objetivo de realizar estudos de m?todos de recupera??o avan?ada de ?leo. Os resultados obtidos neste trabalho mostraram que a configura??o de po?os aplicada para este caso apresentou uma leve melhora em rela??o ? configura??o convencional de 5 pontos (5-Spot) em termos de fator de recupera??o, no entanto, apresentou menores resultados na avalia??o econ?mica

Made available in DSpace on 2014-12-17T14:08:47Z (GMT). No. of bitstreams: 1 MartinhoQAF_DISSERT.pdf: 3517855 bytes, checksum: e2d79876500fdde55b949a6a832b6ff0 (MD5) Previous issue date: 2011-05-27 / Water injection is the most widely used method for supplementary recovery in many oil fields due to various reasons, like the fact that water is an effective displacing agent of low viscosity oils, the water injection projects are relatively simple to establish and the water availability at a relatively low cost. For design of water injection projects is necessary to do reservoir studies in order to define the various parameters needed to increase the effectiveness of the method. For this kind of study can be used several mathematical models classified into two general categories: analytical or numerical. The present work aims to do a comparative analysis between the results presented by flow lines simulator and conventional finite differences simulator; both types of simulators are based on numerical methods designed to model light oil reservoirs subjected to water injection. Therefore, it was defined two reservoir models: the first one was a heterogeneous model whose petrophysical properties vary along the reservoir and the other one was created using average petrophysical properties obtained from the first model. Comparisons were done considering that the results of these two models were always in the same operational conditions. Then some rock and fluid parameters have been changed in both models and again the results were compared. From the factorial design, that was done to study the sensitivity analysis of reservoir parameters, a few cases were chosen to study the role of water injection rate and the vertical position of wells perforations in production forecast. It was observed that the results from the two simulators are quite similar in most of the cases; differences were found only in those cases where there was an increase in gas solubility ratio of the model. Thus, it was concluded that in flow simulation of reservoirs analogous of those now studied, mainly when the gas solubility ratio is low, the conventional finite differences simulator may be replaced by flow lines simulator the production forecast is compatible but the computational processing time is lower. / A inje??o de ?gua ? o m?todo de recupera??o suplementar mais difundido na maioria dos campos de petr?leo, devido a v?rios motivos, como o fato de a ?gua ser um eficiente agente deslocante de ?leos com baixa viscosidade associado ao fato de ser relativamente f?cil de injetar e de existir grande disponibilidade de ?gua a um custo relativamente baixo de se obter. Para o dimensionamento de um projeto de inje??o de ?gua ? necess?rio efetuar um estudo de reservat?rio com o objetivo de se definir os v?rios par?metros necess?rios para aumentar a efic?cia do m?todo. Para este estudo podem ser utilizados v?rios modelos matem?ticos classificados como anal?ticos ou num?ricos. Este trabalho tem como objetivo efetuar uma an?lise comparativa entre os resultados apresentados por um simulador de linhas de fluxo e um simulador convencional por diferen?a finita, que s?o dois tipos de simuladores de fluxo baseados em m?todos num?ricos, para um modelo de um reservat?rio de petr?leo leve submetido ? inje??o de ?gua. Para tanto foram montados dois modelos de reservat?rio, sendo um modelo heterog?neo e outro homog?neo contendo valores m?dios das propriedades de rocha do primeiro modelo. Foram realizadas compara??es dos resultados destes modelos considerando sempre as mesmas condi??es de opera??o. Em seguida foram alterados alguns par?metros de fluido e de rocha em ambos os modelos e efetuadas novamente compara??es de resultados. A partir do planejamento fatorial, realizado para a an?lise de sensibilidade dos par?metros de reservat?rio, foram escolhidos alguns casos para efetuar an?lise da varia??o dos par?metros operacionais escolhidos que foram a vaz?o de inje??o de ?gua e a localiza??o dos canhoneados. Observou-se que os resultados entre os simuladores s?o bastante similares na maioria dos casos estudados, tendo sido encontrado diverg?ncias apenas nos casos em que h? aumento na raz?o de solubilidade de g?s do modelo. Desta maneira foi conclu?do que o simulador convencional por diferen?as finitas pode ser substitu?do por um simulador por linhas de fluxo em reservat?rios semelhantes ao estudado, quando a raz?o de solubilidade possui valores baixos, sem preju?zo aos resultados de produ??o e com menores tempos de processamento computacional. / 2020-01-01

Made available in DSpace on 2014-12-17T14:08:40Z (GMT). No. of bitstreams: 1 VanessaLAG_DISSERT.pdf: 1481281 bytes, checksum: 8b61d326c9b0fb24441950affcfa1205 (MD5) Previous issue date: 2010-08-20 / Coordena??o de Aperfei?oamento de Pessoal de N?vel Superior / Waterflooding is a technique largely applied in the oil industry. The injected water displaces oil to the producer wells and avoid reservoir pressure decline. However, suspended particles in the injected water may cause plugging of pore throats causing formation damage (permeability reduction) and injectivity decline during waterflooding. When injectivity decline occurs it is necessary to increase the injection pressure in order to maintain water flow injection. Therefore, a reliable prediction of injectivity decline is essential in waterflooding projects. In this dissertation, a simulator based on the traditional porous medium filtration model (including deep bed filtration and external filter cake formation) was developed and applied to predict injectivity decline in perforated wells (this prediction was made from history data). Experimental modeling and injectivity decline in open-hole wells is also discussed. The injectivity of modeling showed good agreement with field data, which can be used to support plan stimulation injection wells / A inje??o de ?gua ? uma t?cnica amplamente utilizada para deslocar o ?leo em dire??o aos po?os produtores e manter a press?o em reservat?rios de petr?leo. Entretanto, part?culas suspensas na ?gua injetada podem ser retidas no meio poroso, causando dano ? forma??o (redu??o de permeabilidade) e perda de injetividade. Quando ocorre essa redu??o de injetividade ? necess?rio aumentar a press?o de inje??o para manter a vaz?o de ?gua injetada. Desse modo, a correta previs?o da perda de injetividade ? essencial em projetos de inje??o de ?gua. Neste trabalho, um simulador, baseado no modelo tradicional da filtra??o em meios porosos (incluindo filtra??o profunda e forma??o do reboco externo), foi desenvolvido e aplicado para prever a perda de injetividade em po?os canhoneados (tal previs?o foi feita a partir de dados de hist?rico). Al?m disso, tamb?m foi discutida a determina??o experimental dos coeficientes do modelo e a perda de injetividade em po?os abertos. A modelagem da injetividade apresentou bom ajuste aos dados de campo, podendo ser utilizada para auxiliar no planejamento de estimula??es de po?os injetores

Submitted by Automa??o e Estat?stica (sst@bczm.ufrn.br) on 2017-03-17T19:32:33Z No. of bitstreams: 1 JoseEdenilsonOliveiraReges_TESE.pdf: 5841325 bytes, checksum: 2ead9ffcd013a5ed21850074ab97c30f (MD5) / Approved for entry into archive by Arlan Eloi Leite Silva (eloihistoriador@yahoo.com.br) on 2017-03-18T00:04:04Z (GMT) No. of bitstreams: 1 JoseEdenilsonOliveiraReges_TESE.pdf: 5841325 bytes, checksum: 2ead9ffcd013a5ed21850074ab97c30f (MD5) / Made available in DSpace on 2017-03-18T00:04:04Z (GMT). No. of bitstreams: 1 JoseEdenilsonOliveiraReges_TESE.pdf: 5841325 bytes, checksum: 2ead9ffcd013a5ed21850074ab97c30f (MD5) Previous issue date: 2016-11-18 / Esta Tese ? uma contribui??o ao desenvolvimento de sensores de vaz?o na ind?stria de petr?leo e g?s. O objetivo geral do trabalho ? apresentar uma metodologia para medir as vaz?es em po?os injetores de ?gua multizonas a partir de perfis de temperatura do fluido e estimar a incerteza da medi??o. Inicialmente, foi apresentada a equa??o cl?ssica de Ramey descrevendo a temperatura do fluido como uma fun??o da vaz?o ao longo do po?o. Ent?o, foram descritos tr?s m?todos de c?lculo das vaz?es a partir do perfil de temperatura e o sensor de vaz?o foi modelado computacionalmente. Em seguida, foram calculadas as vaz?es em quatro po?os injetores multizonas, localizados no Rio Grande do Norte, a partir de perfis de temperatura medidos experimentalmente. As vaz?es calculadas foram comparadas ?s vaz?es medidas no campo. Os resultados preliminares obtidos nos Po?os 1 e 2 foram satisfat?rios. Nestes po?os, os erros m?ximos observados foram de 28,55% (Po?o 1) e 15,72% (Po?o 2). Entretanto, desvios significativos entre as vaz?es calculadas e medidas foram encontrados nos Po?os 3 e 4. Nestes po?os, os erros m?ximos observados foram de 536,84% (Po?o 3) e 335,54% (Po?o 4). Utilizando a expans?o em S?rie de Taylor da equa??o exponencial de Ramey, foi obtida uma fun??o expl?cita, linear, entre a vaz?o ao longo do po?o e a temperatura do fluido, sendo realizada uma an?lise quantitativa da incerteza de medi??o. A partir desta an?lise, foi observado que, devido ? baixa resolu??o nas medi??es de temperatura, a incerteza de medi??o expandida pode atingir cerca de 155,04% da vaz?o calculada. Foi ent?o apresentado um m?todo de c?lculo estoc?stico das vaz?es a partir das distribui??es de probabilidade das temperaturas medidas, atrav?s da Simula??o de Monte Carlo. As novas vaz?es calculadas apresentaram erros m?ximos de 3,67% (Po?o 1), 14,45% (Po?o 2), 14,62% (Po?o 3) e 22,29% (Po?o 4). Logo, a abordagem probabil?stica permitiu que as vaz?es injetadas fossem satisfatoriamente estimadas mesmo nos casos em que a resolu??o do sensor de temperatura era inadequada ? detec??o de pequenas varia??es na temperatura do fluido. Portanto, a metodologia de c?lculo das vaz?es injetadas a partir do perfil de temperatura do fluido foi validada com sucesso. / This thesis is a contribution to the development of flow sensors in oil and gas industry. The main objective of this work is presenting a methodology to measure the flow rates into multiple-zone water-injection wells from fluid temperature profiles and estimate the measurement uncertainty. First, the classical Ramey equation describing the fluid temperature as a function of flow was presented. Then, three methods to calculate the flow rates from temperature profile were described and the flow sensor was computationally modeled. Next, the flow rates into four multiple-zone injection-wells, located in Rio Grande do Norte, were calculated from temperature profiles experimentally measured. The calculated flow rates were compared to the measured flow rates. The preliminary results, obtained from Wells 1 and 2, were satisfactory. In these wells, the maximum errors were equals to 28,55% (Well 1) and 15,72% (Well 2). However, significant deviations between the calculated and the measured flow rates were found at Wells 3 and 4. In these wells, the maximum errors were equals to 536,84% (Well 3) and 335,54% (Well 4). The Ramey equation was expanded in Taylor Series and linearized to obtain an explicit, linear, function between the flow and the fluid temperature. Then, a quantitative uncertainty analysis was performed. From this analysis, it was observed, due the temperature sensor resolution, the expanded measurement uncertainty may achieve about 155,04% of the calculated flow rate. Then, the injected flow rates were stochastically recalculated from the probability distributions of the measured temperatures, through a Monte Carlo simulation. The new calculated flow rates presented maximum errors of 3,67% (Well 1), 14,45% (Well 2), 14,62% (Well 3) and 22,29% (Well 4). This probabilistic approach allowed injected flow rates to be estimated even in the cases where the temperature sensor resolution was inadequate to detection of small variations into the fluid temperature. Therefore, the methodology to calculate the injected flow rates from the fluid temperature profile was successfully validated.