Made available in DSpace on 2014-12-17T15:42:08Z (GMT). No. of bitstreams: 1 GilianeCMNS_DISSERT.pdf: 1750841 bytes, checksum: cedbb003a4fc658825db6f8e66611748 (MD5) Previous issue date: 2013-06-25 / In this research the removal of light and heavy oil from disintegrated limestone was investigated with use of microemulsions. These chemical systems were composed by surfactant, cosurfactant, oil phase and aqueous phase. In the studied systems, three points in the water -rich microemulsion region of the phase diagrams were used in oil removal experiments. These microemulsion systems were characterized to evaluate the influence of particle size, surface tension, density and viscosity in micellar stability and to understand how the physical properties can influence the oil recovery process. The limestone rock sample was characterized by thermogravimetry, BET area, scanning electron microscopy and X-ray fluorescence. After preparation, the rock was placed in contact with light and heavy oil solutions to allow oil adsorption. The removal tests were performed to evaluate the influence of contact time (1 minute, 30 minutes, 60 minutes and 120 minutes), the concentration of active matter (20, 30 and 40 %), different cosurfactants and different oil phases. For the heavy oil, the best result was on SME 1, with 20 % of active matter, 1 minute of contact time, with efficiency of 93,33 %. For the light oil, also the SME 1, with 20 % of active matter, 120 minutes of contact time, with 62,38 % of efficiency. From the obtained results, it was possible to conclude that microemulsions can be considered as efficient chemical systems for oil removal from limestone formations / O presente trabalho objetivou estudar a remo??o de fra??es de ?leo leve e pesado em rocha calc?ria desintegrada atrav?s de sistemas microemulsionados, comparando as efici?ncias de remo??o em diferentes concentra??es de mat?ria ativa (C/T) e tempo de contato. Os sistemas microemulsionados (SME) s?o constitu?dos por tensoativo, cotensoativo, fase oleosa e fase aquosa. Nos sistemas estudados, tr?s pontos ricos em ?gua da regi?o de microemuls?o foram utilizados para verificar a efici?ncia de remo??o. Os sistemas foram caracterizados para avaliar a influ?ncia do tamanho do agregado, tens?o superficial e viscosidade na estabilidade micelar e compreender como as propriedades f?sicas podem influenciar o processo de remo??o de ?leo. A amostra de rocha calc?ria foi caracterizada por Termogravimetria, ?rea BET, Microscopia Eletr?nica de Varredura, Difra??o de Raios-X e Fluoresc?ncia de Raios-X. A rocha preparada foi colocada em contato com solu??o de ?leo leve e pesado em xileno para permitir a adsor??o de ?leo. Os testes de remo??o foram realizados a fim de avaliar a influ?ncia do tempo de contato (1, 30, 60 e 120 minutos), da concentra??o de mat?ria ativa (20, 30 e 40%), do cotensoativo e da fase oleosa. Para o ?leo pesado, o melhor resultado foi para o SME 1, com 20 % de mat?ria ativa, no tempo de 1 minuto, com 93,33 % de efici?ncia. Para o ?leo leve, o SME 1 no percentual de 20 %, com 120 minutos apresentou o melhor rendimento, com 62,38 %. A partir dos resultados obtidos, concluiu-se que os sistemas microemulsionados apresentam-se como uma alternativa eficaz para remo??o de ?leo em forma??es calc?rias

Made available in DSpace on 2014-12-17T14:08:30Z (GMT). No. of bitstreams: 1 EdneyRVPG.pdf: 3193441 bytes, checksum: 9108a5643f51fcfe4a8b7479be215c58 (MD5) Previous issue date: 2008-08-18 / Currently a resource more and more used by the petroleum industry to increase the efficiency of steam flood mechanism is the addition of solvents. The process can be understood as a combination of a thermal method (steam injection) with a miscible method (solvent injection), promoting, thus, the reduction of interfacial tensions and oil viscosity. The use of solvent alone tends to be limited because of its high cost. When co-injected with steam, the vaporized solvent condenses in the cooler regions of the reservoir and mixes with the oil, creating a zone of low viscosity between the steam and the heavy oil. The mobility of the displaced fluid is then improved, resulting in an increase of oil recovery. To better understand this improved oil recovery method, a numerical study of the process was done contemplating the effects of some operational parameters (distance between wells, injection steam rate, kind of solvent and injected solvent volume)on the accumulated production of oil, recovery factor and oil-steam rate. Semisynthetic models were used in this study but reservoir data can be extrapolated for practical applications situations on Potiguar Basin. Simulations were performed in STARS (CMG, 2007.11). It was found that injected solvent volumes increased oil recovery and oil rates. Further the majority of the injected solvent was produced and can be recycled / Um recurso cada vez mais utilizado pela ind?stria petrol?fera para aumentar a efici?ncia do mecanismo de inje??o de vapor ? a adi??o de solventes. O processo pode ser compreendido como a combina??o de um m?todo t?rmico (inje??o de vapor) com um m?todo misc?vel (inje??o de solvente), promovendo, dessa forma, a redu??o das tens?es interfaciais e da viscosidade do ?leo. O uso do solvente sozinho tende a ser limitado, em fun??o do seu alto custo. Quando coinjetado com o vapor, o solvente vaporizado condensa nas regi?es menos quentes do reservat?rio e mistura-se ao ?leo, criando uma zona de baixa viscosidade entre o vapor e o ?leo pesado. A mobilidade do fluido deslocado ? ent?o melhorada, implicando num aumento do fator de recupera??o. Para melhor compreender esse mecanismo de recupera??o avan?ada, foi realizado um estudo num?rico, onde se verificou a sensibilidade de alguns par?metros operacionais (dist?ncia entre po?os, vaz?o de inje??o de vapor, tipo de solvente injetado e quantidade de solvente) sobre a produ??o acumulada de ?leo, o fator de recupera??o e a raz?o ?leo-vapor. Neste estudo, foram utilizados modelos semi-sint?ticos, por?m com dados de reservat?rio que podem ser extrapolados para situa??es de aplica??es pr?ticas na Bacia Potiguar. As simula??es foram realizadas no m?dulo STARS (Steam, Thermal, and Advanced Processes Reservoir Simulator) do programa da CMG (Computer Modelling Group), vers?o 2007.11. Os resultados mostraram que a presen?a do solvente nas quantidades analisadas melhorou os fatores de recupera??o e as vaz?es de ?leo. Al?m disso, a maior parte do solvente injetado foi produzido, podendo ser reciclado

Made available in DSpace on 2014-12-17T14:08:34Z (GMT). No. of bitstreams: 1 DayanaLSpdf.pdf: 1986697 bytes, checksum: 096c92db6f636c1bab0aeee590522e53 (MD5) Previous issue date: 2009-07-31 / Petr?leo Brasileiro SA - PETROBRAS / Currently, due to part of world is focalized to petroleum, many researches with this theme have been advanced to make possible the production into reservoirs which were classified as unviable. Because of geological and operational challenges presented to oil recovery, more and more efficient methods which are economically successful have been searched. In this background, steam flood is in evidence mainly when it is combined with other procedures to purpose low costs and high recovery factors. This work utilized nitrogen as an alternative fluid after steam flood to adjust the best combination of alternation between these fluids in terms of time and rate injection. To describe the simplified economic profile, many analysis based on liquid cumulative production were performed. The completion interval and injection fluid rates were fixed and the oil viscosity was ranged at 300 cP, 1.000 cP and 3.000 cP. The results defined, for each viscosity, one specific model indicating the best period to stop the introduction of steam and insertion of nitrogen, when the first injected fluid reached its economic limit. Simulations in physics model defined from one-eighth nine-spot inverted were realized using the commercial simulator Steam, Thermal and Advanced Processes Reservoir Simulator STARS of Computer Modelling Group CMG / Atualmente, pelo fato de parte do mundo estar voltada para a ind?stria do petr?leo, as pesquisas na ?rea t?m avan?ado de modo a tornar poss?vel at? mesmo a produ??o em reservat?rios at? ent?o vistos como invi?veis. Em virtude dos desafios geol?gicos e operacionais apresentados para recuperar o ?leo, cada vez mais se intensifica a busca por m?todos mais eficientes e lucrativos. Neste cen?rio, a inje??o de vapor merece destaque, sobretudo, quando combinada com outros procedimentos visando assim, reduzir os custos, ao mesmo tempo em que aumenta o fator de recupera??o. O presente trabalho utilizou o nitrog?nio como fluido alternativo ap?s a inje??o de vapor a fim de ajustar a melhor combina??o de altern?ncia desses fluidos em termos do tempo e vaz?o de inje??o. Para tra?ar um perfil econ?mico simplificado do processo, realizaram-se an?lises com base na produ??o acumulada l?quida. O intervalo de completa??o e as vaz?es dos fluidos de inje??o foram fixados e variou-se a viscosidade do ?leo em 300 cP, 1.000 cP e 3.000 cP. Os resultados definiram, para cada viscosidade, um modelo espec?fico indicando o melhor per?odo para interrup??o do vapor e inser??o do nitrog?nio, quando o primeiro fluido injetado atingiu seu limite econ?mico. As simula??es foram realizadas em um modelo f?sico definido a partir de 1/8 (um oitavo) do padr?o nine-spot invertido, utilizando o simulador comercial Steam, Thermal and Advanced Processes Reservoir Simulator STARS do Computer Modelling Group CMG

Submitted by Automa??o e Estat?stica (sst@bczm.ufrn.br) on 2016-08-27T00:31:10Z No. of bitstreams: 1 AlleneDeLourdesSoutoDeMoura_DISSERT.pdf: 5567423 bytes, checksum: 8ec48193c0808bf559ec17f275d69b74 (MD5) / Approved for entry into archive by Arlan Eloi Leite Silva (eloihistoriador@yahoo.com.br) on 2016-09-02T20:22:39Z (GMT) No. of bitstreams: 1 AlleneDeLourdesSoutoDeMoura_DISSERT.pdf: 5567423 bytes, checksum: 8ec48193c0808bf559ec17f275d69b74 (MD5) / Made available in DSpace on 2016-09-02T20:22:39Z (GMT). No. of bitstreams: 1 AlleneDeLourdesSoutoDeMoura_DISSERT.pdf: 5567423 bytes, checksum: 8ec48193c0808bf559ec17f275d69b74 (MD5) Previous issue date: 2016-05-06 / Grande parte das reservas de hidrocarbonetos atualmente existentes s?o formadas por ?leos pesados e devido a sua alta viscosidade, os m?todos convencionais n?o s?o capazes de desloca-los at? o po?o produtor de maneira satisfat?ria, deixando um grande volume de ?leo retido no reservat?rio. Um dos m?todos utilizados para a recupera??o de ?leo pesado ? o m?todo t?rmico, que tem como caracter?stica principal reduzir a viscosidade do ?leo facilitando assim seu deslocamento at? o po?o produtor. Os m?todos t?rmicos podem utilizar-se da inje??o de energia em forma de calor no reservat?rio, onde faz com que a temperatura do ?leo aumente, diminuindo assim sua viscosidade e consequentemente melhorando a sua mobilidade. O Nordeste Brasileiro possui principalmente muitos reservat?rios de ?leo pesado, onde ? aplicado o m?todo de inje??o de vapor na forma cont?nua. A inje??o cont?nua de vapor atua tanto termicamente como mecanicamente no reservat?rio, al?m do calor latente transmitido ao reservat?rio aquecer o ?leo nele existente, proporcionando assim uma redu??o da sua viscosidade, ele o desloca at? o po?o produtor. O desempenho deste processo pode ser afetado significativamente por determinados par?metros operacionais e geom?tricos do reservat?rio. O objetivo principal deste trabalho foi estudar diferentes dist?ncias entre po?os no processo de inje??o de vapor, aplicando-o em um reservat?rio semissint?tico com caracter?sticas semelhantes aos encontrados no Nordeste Brasileiro, al?m disso foi realizada uma an?lise econ?mica dos modelos estudados atrav?s do VPL (Valor Presente L?quido). Para realizar o trabalho foi utilizado um programa de simula??o num?rica de reservat?rios da CMG (Computer Modeling Group), o software STARS (Steam, Thermal and Advanced Processes Reservoir Simulator). Verificou-se que, aumentando-se a vaz?o de vapor at? um determinado valor, h? um incremento na produ??o. Em rela??o ?s dist?ncias entre os po?os, quanto menor, mais r?pido o ?leo atinge o po?o produtor, al?m de atingir sua produ??o m?xima antecipadamente em rela??o ?s maiores. Por?m ? indispens?vel analisar a viabilidade econ?mica do projeto, pois de acordo com os resultados uma maior produ??o n?o necessariamente acarretar? em um melhor retorno financeiro. / Some of the existing hydrocarbon reserves currently are comprised of heavy oils and due to its high viscosity, conventional methods are not able to move it until the well producer satisfactorily, leaving large volume of trapped oil in reservoir. One method for heavy oil recovery is the thermal method, which has a main characteristic reduce the oil viscosity facilitating its displacement to the well producer. The thermal methods heat back on energy injection in the form of heat in the reservoir, where it causes the oil temperature increase, reducing so his viscosity and therefore improving their mobility. The Brazilian Northeast has many mainly heavy oil reservoirs, where are implemented continuous steam injection method. The continuous steam injection acts both thermally as mechanically in the reservoir, beside the latent heat transmitted to heat the oil in the reservoir, thus providing a reduction in viscosity, it pushes up the production well. The performance of this process can be significantly affected by certain operating and geometric parameters of the reservoir. The main objective of this work was to study different distances between wells in the steam injection process, applying it in a semi-synthetic reservoir with characteristics similar to those found in Brazilian Northeast and to complete was realized an economic analysis of the models studied using of the NPV (Net Present Value). To do the work was used a numerical simulation program reservoirs of CMG (Computer Modeling Group), the STARS (Steam, Thermal and Advanced Process Reservoir Simulator) software. It was found that increasing the steam flow to a certain value there is an increase in oil production. About the distances, how smaller, faster the oil reaches the production well. However it is essential to analyze the economic feasibility of the project, because of according to the results the largest production not necessarily will bring in a better return.

Made available in DSpace on 2014-12-17T14:08:48Z (GMT). No. of bitstreams: 1 DaviMSBL_DISSERT.pdf: 4742258 bytes, checksum: 95c358d84716a6d20ba53990ae56c3f3 (MD5) Previous issue date: 2011-09-02 / Coordena??o de Aperfei?oamento de Pessoal de N?vel Superior / The world has many types of oil that have a range of values of density and viscosity, these are characteristics to identify whether an oil is light, heavy or even ultraheavy. The occurrence of heavy oil has increased significantly and pointing to a need for greater investment in the exploitation of deposits and therefore new methods to recover that oil. There are economic forecasts that by 2025, the heavy oil will be the main source of fossil energy in the world. One such method is the use of solvent vaporized VAPEX which is known as a recovery method which consists of two horizontal wells parallel to each other, with a gun and another producer, which uses as an injection solvent that is vaporized in order to reduce the viscosity of oil or bitumen, facilitating the flow to the producing well. This method was proposed by Dr. Roger Butler, in 1991. The importance of this study is to analyze how the influence some operational reservoir and parameters are important in the process VAPEX, such as accumulation of oil produced in the recovery factor in flow injection and production rate. Parameters such as flow injection, spacing between wells, type of solvent to be injected, vertical permeability and oil viscosity were addressed in this study. The results showed that the oil viscosity is the parameter that showed statistically significant influence, then the choice of Heptane solvent to be injected showed a greater recovery of oil compared to other solvents chosen, considering the spacing between the wells was shown that for a greater distance between the wells to produce more oil / Existem no mundo diversos tipos de ?leo que apresentam uma diversidade de valores de densidade e viscosidade, essas s?o caracter?sticas para identificar se um ?leo ? leve, pesado ou at? mesmo ultrapesado. A ocorr?ncia de ?leo pesado vem aumentando sensivelmente e apontando uma necessidade de maiores investimentos na explora??o de jazidas e consequentemente em novos m?todos de recupera??o desse ?leo. Existem previs?es econ?micas de que, para o ano 2025, o ?leo pesado seja a principal fonte de energia f?ssil no mundo. Um desses novos m?todos seria a utiliza??o de solvente vaporizado conhecido como VAPEX que ? um m?todo de recupera??o que consiste em dois po?os horizontais paralelos entre si, sendo um injetor e outro produtor, que utiliza como inje??o solvente vaporizado que tem com o prop?sito reduzir a viscosidade do ?leo ou betume, facilitando o escoamento at? o po?o produtor. Esse m?todo foi proposto por Dr. Roger Butler, em 1991. A import?ncia do presente estudo ? analisar como influenciam alguns par?metros operacionais e de reservat?rio, importantes no processo VAPEX, tais como o acumulo de ?leo produzido, no fator de recupera??o, na vaz?o de inje??o e na taxa de produ??o. Par?metros como vaz?o de inje??o, espa?amento entre os po?os, tipo do solvente a ser injetado, permeabilidade vertical e a viscosidade do ?leo foram abordados neste estudo. Os resultados mostraram que a viscosidade do ?leo foi o par?metro que mais mostrou influ?ncia significativa estatisticamente, em seguida a escolha do Heptano como solvente a ser injetado mostrou uma maior recupera??o de ?leo em rela??o aos demais solventes escolhidos. Considerando o espa?amento entre os po?os, foi mostrado que para uma maior dist?ncia entre os po?os h? uma maior produ??o de ?leo

Made available in DSpace on 2014-12-17T14:08:49Z (GMT). No. of bitstreams: 1 EdsonAA_DISSERT.pdf: 3674397 bytes, checksum: 68989b5d2aabcb74990cc326c009fbc6 (MD5) Previous issue date: 2012-02-17 / The method "toe-to-heel air injection" (THAITM) is a process of enhanced oil recovery, which is the integration of in-situ combustion with technological advances in drilling horizontal wells. This method uses horizontal wells as producers of oil, keeping vertical injection wells to inject air. This process has not yet been applied in Brazil, making it necessary, evaluation of these new technologies applied to local realities, therefore, this study aimed to perform a parametric study of the combustion process with in-situ oil production in horizontal wells, using a semi synthetic reservoir, with characteristics of the Brazilian Northeast basin. The simulations were performed in a commercial software "STARS" (Steam, Thermal, and Advanced Processes Reservoir Simulator), from CMG (Computer Modelling Group). The following operating parameters were analyzed: air rate, configuration of producer wells and oxygen concentration. A sensitivity study on cumulative oil (Np) was performed with the technique of experimental design, with a mixed model of two and three levels (32x22), a total of 36 runs. Also, it was done a technical economic estimative for each model of fluid. The results showed that injection rate was the most influence parameter on oil recovery, for both studied models, well arrangement depends on fluid model, and oxygen concentration favors recovery oil. The process can be profitable depends on air rate / O m?todo toe-to-heel air injection (THAITM) ? um processo de recupera??o de petr?leo avan?ado, que consiste na integra??o da combust?o in-situ com os avan?os tecnol?gicos na perfura??o de po?os horizontais. Este m?todo utiliza po?os horizontais como produtores de ?leo, mantendo po?os injetores verticais para a inje??o de ar. Este processo ainda n?o foi aplicado no Brasil, tornando necess?rio, avalia??o destas novas tecnologias aplicadas ?s realidades locais, por isso, este trabalho teve como objetivo principal realizar um estudo param?trico do processo de combust?o in-situ com produ??o de ?leo em po?os horizontais, usando um reservat?rio semi sint?tico, com caracter?sticas das encontradas no Nordeste Brasileiro. As simula??es foram realizadas em um programa comercial de processos t?rmicos, denominado STARS (Steam, Thermal, and Advanced Processes Reservoir Simulator), da empresa CMG (Computer Modelling Group). Foram realizadas an?lises dos par?metros operacionais: vaz?es de inje??o, configura??o dos po?os e concentra??o de oxig?nio. O estudo de sensibilidade dos fatores foi realizado com a t?cnica de an?lise de planejamento experimental, com uma combina??o de dois e tr?s n?veis (32x22), totalizando 36 simula??es, 18 para cada modelo, em fun??o da produ??o acumulada de ?leo (Np). Tamb?m foi realizada uma estimativa econ?mica de an?lise de custo para cada modelo de fluido. Os resultados mostraram que a configura??o de po?os e a vaz?o de inje??o foram o par?metro que apresentou maior influ?ncia no ?leo recuperado para os dois modelos de fluidos analisados, respectivamente, que a configura??o de po?os ? influenciada pelo modelo de fluido, e que um aumento da concentra??o de oxig?nio favorece a recupera??o de ?leo, no processo estudado. Tamb?m foi encontrado que o processo pode ser rent?vel dependendo da quantidade de ar injetado no processo

Made available in DSpace on 2014-12-17T14:08:55Z (GMT). No. of bitstreams: 1 TayllandyaSP_DISSERT.pdf: 2803522 bytes, checksum: 516959be83003bd573c721b4ad05b984 (MD5) Previous issue date: 2013-11-06 / Conselho Nacional de Desenvolvimento Cient?fico e Tecnol?gico / Nowadays, most of the hydrocarbon reserves in the world are in the form of heavy oil, ultra - heavy or bitumen. For the extraction and production of this resource is required to implement new technologies. One of the promising processes for the recovery of this oil is the Expanding Solvent Steam Assisted Gravity Drainage (ES-SAGD) which uses two parallel horizontal wells, where the injection well is situated vertically above the production well. The completion of the process occurs upon injection of a hydrocarbon additive at low concentration in conjunction with steam. The steam adds heat to reduce the viscosity of the oil and solvent aids in reducing the interfacial tension between oil/ solvent. The main force acting in this process is the gravitational and the heat transfer takes place by conduction, convection and latent heat of steam. In this study was used the discretized wellbore model, where the well is discretized in the same way that the reservoir and each section of the well treated as a block of grid, with interblock connection with the reservoir. This study aims to analyze the influence of the pressure drop and heat along the injection well in the ES-SAGD process. The model used for the study is a homogeneous reservoir, semi synthetic with characteristics of the Brazilian Northeast and numerical simulations were performed using the STARS thermal simulator from CMG (Computer Modelling Group). The operational parameters analyzed were: percentage of solvent injected, the flow of steam injection, vertical distance between the wells and steam quality. All of them were significant in oil recovery factor positively influencing this. The results showed that, for all cases analyzed, the model considers the pressure drop has cumulative production of oil below its respective model that disregards such loss. This difference is more pronounced the lower the value of the flow of steam injection / Atualmente, a maior parte das reservas de hidrocarbonetos no mundo se encontram na forma de ?leo pesado, ultra-pesado ou betume. Para a extra??o e produ??o desse recurso ? necess?ria a implanta??o de novas tecnologias. Um dos processos promissores para a recupera??o desse ?leo ? a drenagem gravitacional assistida com vapor e solvente (ESSAGD) que utiliza dois po?os horizontais paralelos, onde o injetor ? disposto acima do produtor. A realiza??o do processo se d? mediante a inje??o de um aditivo de hidrocarboneto em baixa concentra??o em conjunto com vapor. O vapor contribui com calor para redu??o da viscosidade do ?leo e o solvente ajuda na miscibilidade, reduzindo a tens?o interfacial entre ?leo/solvente. A principal for?a atuante neste processo ? a gravitacional e a transfer?ncia de calor ocorre por meio da condu??o, convec??o e pelo calor latente do vapor. Neste estudo foi utilizado o modelo discretizado, onde o po?o ? discretizado da mesma forma que o reservat?rio, sendo cada se??o do po?o tratada como um bloco da grade, com conex?o interblocos com o reservat?rio. O presente trabalho tem como objetivo analisar a influ?ncia da perda de carga e calor ao longo do po?o injetor no processo ES-SAGD. O modelo utilizado para estudo trata-se de um reservat?rio homog?neo, semissint?tico com caracter?sticas do Nordeste Brasileiro e as simula??es num?ricas foram realizadas atrav?s do simulador t?rmico STARS da CMG (Computer Modelling Group). Os par?metros operacionais analisados foram: porcentagem de solvente injetado, vaz?o de inje??o de vapor, dist?ncia vertical entre os po?os e qualidade de vapor. Todos eles foram significativos no Fator de Recupera??o de ?leo. Os resultados demonstraram que, para todos os casos analisados, o modelo que considera a perda de carga apresenta produ??o acumulada de ?leo inferior ao seu respectivo modelo que desconsidera tal perda. Essa diferen?a ? mais acentuada quanto menor o valor da vaz?o de inje??o de vapor

Made available in DSpace on 2014-12-17T14:08:56Z (GMT). No. of bitstreams: 1 HeloizeSP_DISSERT.pdf: 5210676 bytes, checksum: 2206731cf8d9981475df85f8e57f31d2 (MD5) Previous issue date: 2014-03-06 / The occurrence of heavy oil reservoirs have increased substantially and, due to the high viscosity characteristic of this type of oil, conventional recovery methods can not be applied. Thermal methods have been studied for the recovery of this type of oil, with a main objective to reduce its viscosity, by increasing the reservoir temperature, favoring the mobility of the oil and allowing an increasing in the productivity rate of the fields. In situ combustion (ISC) is a thermal recovery method in which heat is produced inside the reservoir by the combustion of part of the oil with injected oxygen, contrasting with the injection of fluid that is heated in the surface for subsequent injection, which leads to loss heat during the trajectory to the reservoir. The ISC is a favorable method for recovery of heavy oil, but it is still difficult to be field implemented. This work had as an objective the parametric analysis of ISC process applied to a semi-synthetic reservoir with characteristics of the Brazilian Northeast reservoirs using vertical production and vertical injection wells, as the air flow injection and the wells completions. For the analysis, was used a commercial program for simulation of oil reservoirs using thermal processes, called Steam, Thermal and Advanced Processes Reservoir Simulator (STARS) from Computer Modelling Group (CMG). From the results it was possible to analyze the efficiency of the ISC process in heavy oil reservoirs by increasing the reservoir temperature, providing a large decrease in oil viscosity, increasing its mobility inside the reservoir, as well as the improvement in the quality of this oil and therefore increasing significantly its recovered fraction. Among the analyzed parameters, the flow rate of air injection was the one which had greater influence in ISC, obtaining higher recovery factor the higher is the flow rate of injection, due to the greater amount of oxygen while ensuring the maintenance of the combustion front / A ocorr?ncia de ?leos pesados e ultrapesados v?m aumentando sensivelmente e, devido ? alta viscosidade caracter?stica deste tipo de ?leo, n?o podem ser aplicados os m?todos convencionais de recupera??o. M?todos t?rmicos v?m sendo estudados para recupera??o deste tipo de ?leo, tendo como principal objetivo reduzir a sua viscosidade atrav?s do aumento da temperatura do reservat?rio, favorecendo a mobilidade do ?leo e permitindo um aumento no ?ndice de produtividade dos campos. A Combust?o in situ (CIS) ? um m?todo t?rmico de recupera??o em que o calor ? produzido dentro do reservat?rio pela combust?o de parte do ?leo com oxig?nio injetado, contrastando com a inje??o de fluido aquecido ainda na superf?cie para posterior inje??o, o que acarreta perda de calor durante o trajeto ao reservat?rio. A CIS ? um m?todo prop?cio para recupera??o de ?leo pesado, por?m ainda ? complexo de ser implementado. Este trabalho teve como objetivo a an?lise param?trica do processo CIS aplicado a um reservat?rio semissint?tico com caracter?sticas do Nordeste Brasileiro utilizando po?os verticais de produ??o e inje??o, assim como a vaz?o de inje??o de ar e as completa??es dos po?os. Para an?lise do m?todo foi utilizado um programa comercial de simula??o de reservat?rios de petr?leo usando processos t?rmicos, denominado Steam, Thermal and Advanced Processes Reservoir Simulator (STARS) do Computer Modelling Group (CMG). A partir dos resultados obtidos foi poss?vel comprovar a efici?ncia do processo CIS em reservat?rios de ?leo pesado atrav?s do aumento da temperatura do reservat?rio, promovendo uma grande diminui??o na viscosidade do ?leo, aumentando sua mobilidade no interior do reservat?rio, assim como a melhora na qualidade desse ?leo e aumentando assim, significativamente a sua fra??o recuperada. Dentre os par?metros analisados, a vaz?o de inje??o de ar foi a que apresentou maior influ?ncia no processo CIS, obtendo maior fator de recupera??o quanto maior a vaz?o de inje??o, sendo devido a maior quantidade de oxig?nio garantindo a manuten??o da frente de combust?o

Made available in DSpace on 2014-12-17T14:09:14Z (GMT). No. of bitstreams: 1 EdneyRVPG_TESE.pdf: 5370155 bytes, checksum: 315c7c0efbbd205da67094e4ae12330e (MD5) Previous issue date: 2012-09-03 / Coordena??o de Aperfei?oamento de Pessoal de N?vel Superior / A significant fraction of the hydrocarbon reserves in the world is formed by heavy oils. From the thermal methods used to recovery these resources, Steamflooding has been one of the main economically viable alternatives. In Brazil, this technology is widely used by Petrobras in Northeast fields. Latent heat carried by steam heats the oil in the reservoir, reducing its viscosity and facilitating the production. In the last years, an alternative more and more used by the oil industry to increase the efficiency of this mechanism has been the addition of solvents. When co-injected with steam, the vaporized solvent condenses in the cooler regions of the reservoir and mixes with the oil, creating a low viscosity zone between the steam and the heavy oil. The mobility of the displaced fluid is then improved, resulting in an increase of oil recovery. To better understand this improved oil recovery method and investigate its applicability in reservoirs with properties similar to those found in Potiguar Basin, a numerical study was done to analyze the influence of some operational parameters (steam injection rate, injected solvent volume and solvent type) on oil recovery. Simulations were performed in STARS ("Steam, Thermal, and Advanced Processes Reservoir Simulator"), a CMG ("Computer Modelling Group") program, version 2009.10. It was found that solvents addition to the injected steam not only anticipated the heated oil bank arrival to the producer well, but also increased the oil recovery. Lower cold water equivalent volumes were required to achieve the same oil recoveries from the models that injected only steam. Furthermore, much of the injected solvent was produced with the oil from the reservoir / Uma por??o significativa das reservas de hidrocarbonetos atualmente existentes no mundo ? formada por ?leos pesados. Dentre os m?todos t?rmicos utilizados para a recupera??o desse tipo de recurso, a Inje??o Cont?nua de Vapor tem se constitu?do como uma das principais alternativas economicamente vi?veis. No Brasil, essa tecnologia ? largamente utilizada pela Petrobras em campos localizados na regi?o Nordeste. O calor latente transportado pelo vapor aquece o ?leo do reservat?rio, reduzindo sua viscosidade e facilitando a produ??o. Nos ?ltimos anos, uma alternativa cada vez mais utilizada pela ind?stria para aumentar a efici?ncia desse mecanismo tem sido a adi??o de solventes. Quando coinjetado com o vapor, o solvente vaporizado se condensa nas regi?es menos aquecidas do reservat?rio e mistura-se ao ?leo, criando uma zona de baixa viscosidade entre o vapor e o ?leo pesado. A mobilidade do fluido deslocado ? ent?o melhorada, implicando num aumento da fra??o recuperada. Para melhor compreender esse mecanismo de recupera??o avan?ada e investigar a sua aplicabilidade em reservat?rios com caracter?sticas semelhantes aos encontrados na Bacia Potiguar, foi realizado um estudo num?rico, onde se verificou a influ?ncia de alguns par?metros operacionais (vaz?o de inje??o de vapor, volume de solvente injetado e tipo de solvente) sobre a recupera??o de ?leo. As simula??es foram realizadas no m?dulo STARS ( Steam, Thermal, and Advanced Processes Reservoir Simulator ) do programa da CMG ( Computer Modelling Group ), vers?o 2009.10. Verificou-se que a adi??o de solventes ao vapor injetado n?o s? antecipou a chegada do banco de ?leo aquecido ao po?o produtor como tamb?m incrementou a recupera??o de ?leo. Menores volumes de ?gua fria equivalente foram requeridos para se obter as mesmas fra??es recuperadas dos modelos que s? injetaram vapor. Al?m disso, boa parte do solvente injetado foi produzido juntamente com o ?leo do reservat?rio

Submitted by Automa??o e Estat?stica (sst@bczm.ufrn.br) on 2016-07-11T17:35:18Z No. of bitstreams: 1 MirellaLopesDaRocha_DISSERT.pdf: 4193744 bytes, checksum: f2fd7a25cfa4b47013fb029c75d748a3 (MD5) / Approved for entry into archive by Arlan Eloi Leite Silva (eloihistoriador@yahoo.com.br) on 2016-07-18T17:12:19Z (GMT) No. of bitstreams: 1 MirellaLopesDaRocha_DISSERT.pdf: 4193744 bytes, checksum: f2fd7a25cfa4b47013fb029c75d748a3 (MD5) / Made available in DSpace on 2016-07-18T17:12:19Z (GMT). No. of bitstreams: 1 MirellaLopesDaRocha_DISSERT.pdf: 4193744 bytes, checksum: f2fd7a25cfa4b47013fb029c75d748a3 (MD5) Previous issue date: 2016-02-22 / Com um n?mero crescente de campos maduros, a recupera??o de ?leo pesado tem se apresentado um dos grandes desafios do setor petrol?fero. O Nordeste Brasileiro, por exemplo, possui in?meros reservat?rio de ?leo pesado que possam vir a ser explorados com a utiliza??o de m?todos t?rmicos. Dentre os tipos de m?todos utilizados para ?leos pesados, destaca-se o m?todo da combust?o in-situ, uma t?cnica no qual o calor ? produzido dentro do reservat?rio, diferente da inje??o de fluido aquecido em que o calor ? gerado na superf?cie e transportado para o reservat?rio. Neste tipo de processo, ? comum utilizar po?os verticais como injetores e produtores. Contudo, m?todos que utilizam po?os horizontais como produtores de ?leo s?o cada vez mais estudados devido ? maior ?rea de contato entre a forma??o e a frente de combust?o. Sendo assim, o objetivo principal do presente trabalho foi estudar as diferentes configura??es de po?os (CIS, THAITM e CAGD) no processo de combust?o in-situ, na recupera??o de ?leo, utilizando um reservat?rio semissint?tico com caracter?sticas do Nordeste Brasileiro. O m?todo ?toe-to-heel air injection? (THAITM) ? um processo de recupera??o de petr?leo avan?ado, que consiste na integra??o da combust?o in-situ com os avan?os tecnol?gicos na perfura??o de po?os horizontais. Este m?todo utiliza po?os horizontais como produtores de ?leo, mantendo po?os injetores verticais para a inje??o de ar. O processo de drenagem de ?leo por diferencial gravitacional assistida com combust?o (CAGD) ? um sistema integrado, nesta configura??o o po?o injetor horizontal ? perfurado na parte superior de forma??o,com um po?o horizontal produtor na se??o inferior. As simula??es foram realizadas em um programa comercial de processos t?rmicos, denominado ?STARS? (Steam, Thermal, and Advanced Processes Reservoir Simulator), da empresa CMG (Computer Modelling Group). Foi realizada uma an?lise da vaz?o de inje??o de ar e verificou-se que cada m?todo possu?a um limite m?ximo de inje??o para o modelo base, mostrando que passando desse limite de inje??o de ar, havia redu??o da produ??o acumulada de ?leo. Foram realizadas an?lises dos par?metros operacionais: vaz?es de inje??o, configura??o e completa??o dos po?os. Na an?lise de sensibilidade foi encontrado que a vaz?o de inje??o de ar apresentou maior influ?ncia no m?todo THAI, j? no m?todo CIS a completa??o dos po?os foi o par?metro mais influente e no CAGD a configura??o de po?os foi o que apresentou maior influ?ncia na fra??o recuperada. Os resultados econ?micos mostraram que o melhor caso obtido foi o m?todo CAGD,pois, apesar de possuir maior custo inicial, foi o que apresentou melhor retorno financeiro quando comparado com os melhores casos do CIS e THAI. / With an increasing number of mature fields, heavy oil recovery has performed one of the great challenges of the oil industry. The Brazilian Northeast, for example, has numerous heavy oil reservoirs are explored with the use of thermal methods. Among the types of methods used for heavy oil, there is the method of in-situ combustion, a technique in which heat is produced within the container, unlike the injection of heated fluid when the heat is generated at the surface and transported to the reservoir. In this type of process, it is common to use vertical wells as injectors and producers. However, methods which use horizontal wells like oil producers are increasingly studied because of greater contact area between the formation and combustion front. Thus, the main objective of this work was to study the different configurations of wells (CIS THAITM and CAGD) in the process of in-situ combustion in oil recovery using a semi-synthetic tank with Brazilian Northeast features. The method "toe-to-heel air injection" (THAITM) is a process of enhanced oil recovery, which is the integration of in-situ combustion with technological advances in drilling horizontal wells. This method uses horizontal wells such as oil producers, keeping vertical injection wells for injecting air. The oil drain process by differential gravitational assisted with combustion (CAGD) is an integrated, in this configuration the horizontal injector well is drilled at the top formation with a horizontal production well in the lower section. The simulations were performed in a commercial program of thermal processes, called "STARS" (Steam, Thermal, and Advanced Processes Reservoir Simulator), the company CMG (Computer Modelling Group). An analysis of the air flow injection was performed and it was found that each method had a maximum injection to the base model, a show that through this air injection limit was reduced cumulative production of oil. Analyses of operating parameters were used: injection flow, configuration and completion of wells. In the sensitivity analysis we found that the air injection flow showed greater influence on THAI method, since the CIS method the completion of the wells was the most influential parameter and CAGD configuration wells showed the greatest influence in the recovered fraction. The economic results have shown that the best case obtained in CAGD method because, despite having higher initial cost showed the best financial return compared to the best cases the CIS and THAI.