Made available in DSpace on 2014-12-17T14:08:51Z (GMT). No. of bitstreams: 1 LiaraTV_DISSERT.pdf: 1753803 bytes, checksum: 5e53187cb6e33e84a341ab8ca9fd48da (MD5) Previous issue date: 2011-12-22 / Coordena??o de Aperfei?oamento de Pessoal de N?vel Superior / The objective of the thermal recovery is to heat the resevoir and the oil in it to increase its recovery. In the Potiguar river basin there are located several heavy oil reservoirs whose primary recovery energy provides us with a little oil flow, which makes these reservoirs great candidates for application of a method of recovery advanced of the oil, especially the thermal. The steam injection can occur on a cyclical or continuous manner. The continuous steam injection occurs through injection wells, which in its vicinity form a zone of steam that expands itself, having as a consequence the displace of the oil with viscosity and mobility improved towards the producing wells. Another possible mechanism of displacement of oil in reservoirs subjected to continuous injection of steam is the distillation of oil by steam, which at high temperatures; their lighter fractions can be vaporized by changing the composition of the oil produced, of the oil residual or to shatter in the amount of oil produced. In this context, this paper aims to study the influence of compositional models in the continuous injection of steam through in the analysis of some parameters such as flow injection steam and temperature of injection. Were made various leading comparative analysis taking the various models of fluid, varying from a good elementary, with 03 pseudocomponents to a modeling of fluids with increasing numbers of pseudocomponents. A commercial numerical simulator was used for the study from a homogeneous reservoir model with similar features to those found in northeastern Brazil. Some conclusions as the increasing of the simulation time with increasing number of pseudocomponents, the significant influence of flow injection on cumulative production of oil and little influence of the number of pseudocomponents in the flows and cumulative production of oil were found / O objetivo da recupera??o t?rmica ? aquecer o reservat?rio e o ?leo nele existente para aumentar a sua recupera??o. Na Bacia Potiguar existem v?rios reservat?rios de ?leos pesados cuja energia de recupera??o prim?ria nos fornece uma vaz?o de ?leo pequena, o que torna tais reservat?rios ?timos candidatos para aplica??o de um m?todo de recupera??o avan?ada de petr?leo, especialmente o t?rmico. A inje??o de vapor pode ocorrer de forma c?clica ou cont?nua. A inje??o de vapor cont?nua ocorre atrav?s de po?os injetores, pr?ximos aos quais se forma uma zona de vapor que se expande, tendo como conseq??ncia o deslocamento do ?leo com viscosidade e mobilidade melhoradas na dire??o dos po?os produtores. Outro mecanismo poss?vel de deslocamento do ?leo em reservat?rios submetidos ? inje??o cont?nua de vapor ? a destila??o do ?leo por vapor, o qual quando alcan?am altas temperaturas, suas fra??es mais leves podem ser vaporizadas alterando a composi??o do ?leo produzido, do ?leo residual ou impactar na quantidade de ?leo produzida. Nesse contexto, este trabalho objetiva estudar a influ?ncia de modelos composicionais na inje??o cont?nua de vapor atrav?s de uma an?lise de par?metros como vaz?o de inje??o de vapor e temperatura de inje??o. Foram realizadas diversas an?lises comparativas levando os diversos modelos de fluidos, variando de um bem elementar, com 03 pseudocomponentes at? modelagens de fluidos com n?meros crescentes de pseudocomponentes. Foi utilizado um simulador num?rico comercial para o estudo a partir de um modelo de reservat?rio homog?neo com caracter?sticas similares ?s encontradas no Nordeste brasileiro. Algumas conclus?es como o aumento do tempo de simula??o com o aumento do n?mero de pseudocomponentes, a influ?ncia significativa da vaz?o de inje??o na produ??o acumulada de ?leo e a pouca influ?ncia do n?mero de pseudocomponentes nas vaz?es e produ??o acumulada de ?leo foram constatadas

Made available in DSpace on 2014-12-17T14:09:14Z (GMT). No. of bitstreams: 1 MarcosAFR_TESE.pdf: 4983695 bytes, checksum: 6cb8867b58e49a5dd6efc85191c6fa49 (MD5) Previous issue date: 2012-09-03 / Coordena??o de Aperfei?oamento de Pessoal de N?vel Superior / Many of hydrocarbon reserves existing in the world are formed by heavy oils (?API between 10 and 20). Moreover, several heavy oil fields are mature and, thus, offer great challenges for oil industry. Among the thermal methods used to recover these resources, steamflooding has been the main economically viable alternative. Latent heat carried by steam heats the reservoir, reducing oil viscosity and facilitating the production. This method has many variations and has been studied both theoretically and experimentally (in pilot projects and in full field applications). In order to increase oil recovery and reduce steam injection costs, the injection of alternative fluid has been used on three main ways: alternately, co-injected with steam and after steam injection interruption. The main objective of these injection systems is to reduce the amount of heat supplied to the reservoir, using cheaper fluids and maintaining the same oil production levels. This works discusses the use of carbon dioxide, nitrogen, methane and water as an alternative fluid to the steam. The analyzed parameters were oil recoveries and net cumulative oil productions. The reservoir simulation model corresponds to an oil reservoir of 100 m x 100 m x 28 m size, on a Cartesian coordinates system (x, y and z directions). It is a semi synthetic model with some reservoir data similar to those found in Brazilian Potiguar Basin. All studied cases were done using the simulator STARS from CMG (Computer Modelling Group, version 2009.10). It was found that waterflood after steam injection interruption achieved the highest net cumulative oil compared to other fluids injection. Moreover, it was observed that steam and alternative fluids, co-injected and alternately, did not present increase on profitability project compared with steamflooding / Muitas das reservas de hidrocarbonetos existentes em todo o mundo s?o formadas por ?leos pesados (?API entre 10 e 20). Al?m disso, v?rios campos de ?leo pesado est?o maduros e, portanto, oferecem grandes desafios para a ind?stria do petr?leo. Entre os m?todos t?rmicos utilizados para recuperar estes recursos, a inje??o de vapor tem sido a principal alternativa economicamente vi?vel. O calor latente transportado por meio de vapor aquece o reservat?rio, reduzindo a viscosidade do ?leo, facilitando a produ??o. A fim de aumentar a recupera??o de ?leo e reduzir os custos inerentes ? inje??o de vapor, a inje??o de fluidos alternativos tem sido utilizado em combina??o com o vapor das seguintes formas: alternadamente, coinjetados e ap?s a interrup??o da inje??o de vapor. O objetivo principal destes sistemas de inje??o combinada ? reduzir a quantidade de calor fornecida ao reservat?rio utilizando fluidos de menor valor comercial, buscando manter os n?veis de produ??o de ?leo. Este trabalho analisa o uso do di?xido de carbono, nitrog?nio, metano e ?gua como fluido alternativo ao vapor. Os par?metros analisados foram a recupera??o de ?leo e a produ??o acumulada l?quida. O modelo de reservat?rio analisado corresponde a um reservat?rio de dimens?es 100 m x 100 m x 28 m, num sistema de coordenadas cartesianas ( dire??es x, y e z). ? um modelo semissint?tico com alguns dados de reservat?rio semelhantes aos encontrados na Bacia Potiguar, Brasil. Todos os casos estudados foram simulados utilizando o simulador STARS da CMG (Computer Group, Modelagem vers?o 2009.10). Verificou-se que a inje??o de ?gua ap?s a interrup??o de inje??o de vapor alcan?ou melhores resultados em termos de produ??o acumulada l?quida de ?leo em rela??o a inje??o de outros fluidos. Al?m disso, foi observado que o vapor e os fluidos alternativos, coinjetados e alternados, n?o apresentou aumento na rentabilidade do projeto em compara??o com a inje??o cont?nua de vapor

Orientador: Osvair Vidal Trevisan / Dissertação (mestrado) - Universidade Estadual de Campinas, Faculdade de Engenharia Mecanica, Instituto de Geociencias / Made available in DSpace on 2018-08-12T20:49:17Z (GMT). No. of bitstreams: 1 MateoHernandez_JuanAlberto_M.pdf: 12401820 bytes, checksum: 705c41d03544d222731ce816469f47c2 (MD5) Previous issue date: 2006 / Resumo: Neste trabalho são investigados os impactos individual e coletivo dos mecanismos de gás em solução, geração de CO2, destilação, embebição capilar e drenagem gravitacional, sobre a recuperação de óleo e gás, durante a injeção continua de vapor num reservatório naturalmente fraturado contendo óleo pesado. A investigação é feita através de simulação numérica dos fenômenos em modelos padrões de reservatórios. Dois modelos numéricos semelhantes são usados para representar o processo de aquecimento da matriz. O primeiro descreve o aquecimento de uma seção horizontal bidimensional de um bloco da matriz circundado por uma fratura na qual circula vapor. O segundo modelo descreve o aquecimento de um bloco de matriz semelhantemente circundado por uma fratura em que circula vapor, porém na direção vertical, visando agregar o efeito da ação da gravidade. Os estudos foram conduzidos para rochas saturadas com óleo vivo. As propriedades da rocha são as de um reservatório carbonático fraturado real e as propriedades dos fluidos se referem também ao mesmo caso real. Alem disso, as condições operacionais adotadas de pressão e temperatura são as observadas no campo, tornando o estudo e suas conclusões como próprias de um estudo de caso. Os resultados mostram que os principais mecanismos de recuperação de óleo da matriz durante o intervalo de aquecimento de 10 anos, foram os mecanismos de gás em solução e de destilação por arraste de vapor. Este último é o mecanismo de maior importância e é responsável pelo melhoramento da qualidade do óleo produzido / Abstract: In this work, the individual and collective impacts of the mechanisms solution gas drive, CO2 generation, steam distillation, capillary imbibition and drainage gravitational, on the oil and gas recovery, were investigated during the steamflooding of a naturally fractured reservoir containing heavy oil. The investigation was performed for standard reservoir models through numeric simulation. Two similar numerical models represent the matrix heating process. The first describes the heating of a horizontal cross-section of a matrix block surrounded by a fracture, in which the steam is flooding. The second model describes the same method of matrix heating, which was represented in the first model, but in the vertical direction, investigating the action of gravity. The studies were performed for a rock saturated with live oil. The rock properties are the same of a real fractured carbonate reservoir and the fluid properties also refer to the same real case. In addition, the adopted field operational parameters (pressure and temperature) refer to field conditions, turning the study and its conclusions as proper of a case study. The results show that the main mechanisms of oil recovery for the matrix block during the heating interval of 10 years were the integrated action of solution gas and steam distillation. The latter is the dominant mechanism and it is responsible for the improvement in the quality of the produced oil / Mestrado / Reservatórios e Gestão / Mestre em Ciências e Engenharia de Petróleo

Der integrierte Gas-Dampf (GiD-) Prozess mit Wasserrückgewinnung ist ein flexibler Kraft-Wärme-Kopplungsprozess, der die gleichzeitige Bereitstellung von Strom und Wärme teilweise entkoppeln kann. Der effiziente und sparsame Einsatz von fossilen Brennstoffen ist aus ökonomischer wie auch ökologischer Sicht geboten. Die Kraft-Wärme-Kopplung (KWK), die gleichzeitige Erzeugung von Strom und Wärme, ist eine Möglichkeit dafür. Allerdings erfordert die KWK auch eine gleichzeitige Abnahme von Strom und Wärme beziehungsweise deren Speicherung. Sowohl Strom als auch Prozessdampf lassen sich nur aufwendig und damit relativ teuer speichern, weshalb Alternativen gefragt sind. Der GiD-Prozess besteht aus einer Gasturbine mit nachgeschaltetem Abhitzedampfkessel. Die Gasturbine verfügt als Besonderheit über eine Dampfinjektion, die vor, nach oder direkt in die Brennkammer erfolgen kann. Der Abhitzekessel hat zusätzliche Wärmeübertragerflächen um das Abgas bis unter den Taupunkt abzukühlen. Somit kann ein Teil des injizierten Dampfes aus dem Abgas zurückgewonnen und wiederverwendet werden. Der in die Gasturbine injizierte Dampf führt dieser weitere Energie zu. Diese kann entweder zur Leistungssteigerung der Anlage oder zur Reduzierung des fossilen Brennstoffbedarfes genutzt werden. Die erste Option der Leistungssteigerung ist auch als Cheng-Prozess bekannt. Diese Arbeit widmet sich der weniger untersuchten zweiten Möglichkeit der Brennstoffreduzierung. Beim Vergleich des GiD-Prozesses mit verschiedenen anderen Kraftwerks-Prozessen zeigt sich, dass dieser besonders gut für industrielle Anlagen mit Prozessdampfbedarf und einer elektrischen Leistung kleiner 20 MW el geeignet ist. Im Rahmen dieser Arbeit wurde der GiD-Prozess mittels einer Versuchsanlage auf Basis einer Industriegasturbine mit 650 kW el untersucht. Die Arbeit dokumentiert verschiedene Versuchsfahrten und Untersuchungen an dieser Anlage. Die Injektion von Dampf reduziert die Schadstoffemissionen in den zulässigen Bereich und kann sehr flexibel zu einer Steigerung des Anlagenwirkungsgrades von bis zu zwei Prozent führen. Dabei wird der Dampf sehr gleichmäßig in die Versuchsanlage eingebracht, so dass keine signifikanten Änderungen der Abgastemperaturverteilung erkennbar sind. Die Überhitzung des Dampfes kann zu einer weiteren Steigerung des Anlagenwirkungsgrades führen. Die Rückgewinnung des eingebrachten Dampfes ist mit den entsprechenden Wärmeübertragern möglich. Das zurückgewonnene Wasser ist durch die Stickoxide des Abgases verunreinigt und muss entsprechend aufbereitet werden.

Made available in DSpace on 2014-12-17T14:08:34Z (GMT). No. of bitstreams: 1 AntonioRGpdf.pdf: 5141308 bytes, checksum: d76799635535d71b79841802f1a64db0 (MD5) Previous issue date: 2009-07-30 / Petr?leo Brasileiro SA - PETROBRAS / Exploration of heavy oil reservoirs is increasing every year in worldwide, because the discovery of light oil reservoirs is becoming increasingly rare. This fact has stimulated the research with the purpose of becoming viable, technically and economically, the exploration of such oil reserves. In Brazil, in special in the Northeast region, there is a large amount of heavy oil reservoir, where the recovery by the so called secondary methods Water injection or gas injection is inefficient or even impracticable in some reservoirs with high viscosity oils (heavy oils). In this scenario, steam injection appears as an interesting alternative for recover of these kinds of oil reservoirs. Its main mechanism consists of oil viscosity reduction through steam injection, increasing reservoir temperature. This work presents a parametric simulation study of some operational and reservoir variables that had influence on oil recovery in thin reservoirs typically found in Brazilian Northeast Basins, that use the steam injection as improved oil recovery method. To carry out simulations, it was used the commercial software STARS (Steam, Thermal, and Advanced Processes Reservoir Simulator) from CMG (Computer Modeling Group) version 2007.11. Reservoirs variables studied were horizontal permeability, vertical and horizontal permeability ratio, water zone and pay zone thickness ratio, pay zone thickness and thermal conductivity of the rock. Whereas, operational parameters studied were distance between wells and steam injection rate. Results showed that reservoir variables that had more influence on oil recovery were horizontal permeability and water zone and pay zone thickness ratio. In relation to operational variables, results showed that short distances between wells and low steam injection rates improved oil recovery / A cada ano tem ocorrido cada vez mais a explora??o de reservas de ?leo pesado em diversas regi?es do mundo. Isto tem sido feito porque ? cada vez mais rara a exist?ncia de jazidas petrol?feras de ?leos leves. Este fato tem impulsionado in?meras pesquisas em dire??o a tornar vi?vel, do ponto de vista operacional e econ?mico, a explora??o de tais reservas de ?leo. No Brasil, em especial na regi?o Nordeste, existe uma grande quantidade de reservat?rios de ?leos pesados, onde a recupera??o pelos m?todos ditos secund?rios inje??o de ?gua e gases mostram-se ineficientes ou at? invi?veis em alguns reservat?rios que apresentam ?leos de elevada viscosidade. Neste cen?rio, a inje??o de vapor surge como uma alternativa bastante interessante na recupera??o do ?leo desses tipos de reservat?rios. Seu principal mecanismo consiste na redu??o da viscosidade do ?leo por meio da inje??o de um fluido aquecido, no caso, vapor de ?gua, aumentando a temperatura do reservat?rio. Este trabalho apresenta um estudo param?trico das vari?veis de reservat?rio e operacionais que influenciam no fator de recupera??o de ?leo ao longo da vida produtiva do reservat?rio em reservat?rios delgados tipicamente encontrados em Bacias do Nordeste brasileiro, que utilizam a inje??o de vapor como m?todo avan?ado de recupera??o. O estudo foi conduzido atrav?s de simula??o num?rica, utilizando o programa STARS (Steam, Thermal, and Advanced Processes Reservoir Simulator) do grupo CMG (Computer Modelling Group) vers?o 2007.11. As vari?veis de reservat?rio compreenderam a permeabilidade horizontal, a raz?o entre a permeabilidade vertical e horizontal, a raz?o entre a zona de ?gua e a de ?leo, a espessura da zona produtora de ?leo e a condutividade t?rmica da rocha. Enquanto que os par?metros operacionais estudados foram a dist?ncia entre po?os e a vaz?o de inje??o de vapor. Os resultados obtidos mostraram que as vari?veis de reservat?rios que mais influenciaram no fator de recupera??o foram a permeabilidade horizontal e a raz?o entre a zona de ?gua e de ?leo. Com rela??o ?s vari?veis operacionais, menores dist?ncias entre po?os e vaz?es de inje??o melhoram o fator de recupera??o durante a vida produtiva do reservat?rio

Made available in DSpace on 2014-12-17T14:08:35Z (GMT). No. of bitstreams: 1 KeilaRSpdf.pdf: 4445609 bytes, checksum: 3395044458045d549e1940f35912e4a6 (MD5) Previous issue date: 2009-07-31 / Petr?leo Brasileiro SA - PETROBRAS / Due to reservoirs complexity and significantly large reserves, heavy oil recovery has become one of the major oil industry challenges. Thus, thermal methods have been widely used as a strategic method to improve heavy oil recovery. These methods improve oil displacement through viscosity reduction, enabling oil production in fields which are not considered commercial by conventional recovery methods. Among the thermal processes, steam flooding is the most used today. One consequence in this process is gravity segregation, given by difference between reservoir and injected fluids density. This phenomenon may be influenced by the presence of reservoir heterogeneities. Since most of the studies are carried out in homogeneous reservoirs, more detailed studies of heterogeneities effects in the reservoirs during steam flooding are necessary, since most oil reservoirs are heterogeneous. This paper presents a study of reservoir heterogeneities and their influence in gravity segregation during steam flooding process. In this study some heterogeneous reservoirs with physical characteristics similar those found in the Brazilian Northeast Basin were analyzed. To carry out the simulations, it was used the commercial simulator STARS by CMG (Computer Modeling Group) - version 2007.11. Heterogeneities were modeled with lower permeability layers. Results showed that the presence of low permeability barriers can improve the oil recovery, and reduce the effects of gravity segregation, depending on the location of heterogeneities. The presence of these barriers have also increased the recovered fraction even with the reduction of injected steam rate / Devido a complexidade dos reservat?rios e as reservas significativamente grandes, a recupera??o de ?leos pesados tem se tornado um dos grandes desafios da ind?stria petrol?fera. Os processos de recupera??o t?rmica t?m sido largamente empregados como um m?todo estrat?gico para melhorar a recupera??o de ?leo pesado. Estes melhoram o escoamento de ?leos atrav?s da redu??o da viscosidade, viabilizando a produ??o de petr?leo em campos considerados n?o comerciais pelos m?todos convencionais de recupera??o. Entre os m?todos t?rmicos, a inje??o de vapor ? o mais utilizado atualmente. Uma consequ?ncia inerente a este processo ? a segrega??o gravitacional, dada pela diferen?a de densidades dos fluidos do reservat?rio e o injetado. Este fen?meno ? fortemente influenciado pela presen?a de heterogeneidades. Como a maior parte dos estudos ? realizada em reservat?rios homog?neos, necessita-se de um estudo mais detalhado dos efeitos das heterogeneidades nos reservat?rios durante a inje??o de vapor, j? que a maioria dos reservat?rios de petr?leo s?o heterog?neos. Este trabalho apresenta um estudo da influ?ncia da presen?a de heterogeneidades na segrega??o gravitacional durante o processo de inje??o cont?nua de vapor. Os modelos estudados representam reservat?rios heterog?neos com caracter?sticas similares ?s encontradas no Nordeste brasileiro. Para a realiza??o das simula??es, foi utilizado o simulador comercial STARS (Steam, Thermal, and Advanced Processes Reservoir Simulator) do grupo CMG (Computer Modelling Group) vers?o 2007.11. As heterogeneidades foram modeladas como camadas de baixa permeabilidade. Os resultados mostraram que a presen?a de barreiras de baixa permeabilidade pode melhorar a recupera??o de ?leo, al?m de reduzir os efeitos da segrega??o gravitacional, dependendo da localiza??o da heterogeneidade. A presen?a dessas barreiras tamb?m permitiu o aumento da fra??o recuperada mesmo com a redu??o da vaz?o de inje??o do vapor

Made available in DSpace on 2014-12-17T14:08:41Z (GMT). No. of bitstreams: 1 EduardoEFB_DISSERT_1-100.pdf: 2141096 bytes, checksum: 2c8315a9a7567e27a669088e0bbc6350 (MD5) Previous issue date: 2008-12-01 / The application of thermal methods, to increase the recovery of heavy oil in mature fields through drainage with multilateral and horizontal wells, has been thoroughly studied, theorically, experimentally, testing new tools and methods. The continuous injection of steam, through a steam injector well and a horizontal producer well in order to improve horizontal sweep of the fluid reservoir, it is an efficient method. Starting from an heterogeneous model, geologically characterized, modeling geostatistics, set history and identification of the best path of permeability, with seismic 3D, has been dubbed a studying model. It was studied horizontal wells in various directions in relation to the steam and the channel of higher permeability, in eight different depths. Into in the same area were studied, the sensitivity of the trajectories of horizontal wells, according to the depth of navigation. With the purpose of obtaining the highest output of oil to a particular flow, quality, temperature and time for the injection of steam. The wells studied showed a significant improvement in the cumulative oil recovery in one of the paths by promoting an alternative to application in mature fields or under development fields with heavy oil / A aplica??o de m?todos t?rmicos, para aumentar a recupera??o de ?leo pesado em campos maduros atrav?s da drenagem com po?os horizontais e multilaterais, tem sido exaustivamente estudada, te?rica e experimentalmente, testando novas ferramentas e novos m?todos. A inje??o cont?nua de vapor, atrav?s de um po?o injetor e de um po?o horizontal produtor com o objetivo de proporcionar uma varredura dos fluidos do reservat?rio, mostra-se um m?todo eficiente. Partindo de um modelo heterog?neo, geologicamente caracterizado por, modelagem geoestat?stica, ajuste de hist?rico e identifica??o do melhor caminho de permeabilidade, com a s?smica 3D, foi montado um modelo para estudo. Foram estudados po?os horizontais em v?rias dire??es em rela??o ao injetor de vapor e ao canal de maior permeabilidade, em oito profundidades diferentes. Dentro de uma mesma zona foram estudadas, a sensibilidade das trajet?rias de po?os horizontais, em fun??o da profundidade de navega??o. Com a finalidade de obter a maior produ??o acumulada de ?leo a uma determinada vaz?o, qualidade, temperatura e per?odo de inje??o do vapor. Os po?os estudados evidenciam uma melhora significativa na recupera??o acumulada de ?leo em uma das trajet?rias, promovendo uma alternativa de aplica??o em campos maduros ou em desenvolvimento com ?leo pesado

Made available in DSpace on 2014-12-17T15:01:22Z (GMT). No. of bitstreams: 1 GertrudesOQ.pdf: 1545154 bytes, checksum: 8733f5db29d9ddd6780de7e34160f375 (MD5) Previous issue date: 2005-12-16 / Thermal methods made heavy oil production possible in fields where primary recovery failed. Throughout the years steam injection became one of the most important alternatives to increase heavy oil recovery. There are many types of steam injection, and one of them is the cyclic steam injection, which has been used with success in several countries, including Brazil. The process involves three phases: firstly, steam is injected, inside of the producing well; secondly, the well is closed (soak period); and finally, the well is put back into production. These steps constitute one cycle. The cycle is repeated several times until economical production limit is reached. Usually, independent of reservoir type, as the number of cycles increases the cyclic injection turns less efficient. This work aims to analyze rock and reservoir property influence in the cyclic steam injection. The objective was to study the ideal number of cycles and, consequently, process optimization. Simulations were realized using the STARS simulator from the CMG group based in a proposed reservoir model. It was observed that the reservoir thickness was the most important parameter in the process performance, whilst soaking time influence was not significant / Os m?todos t?rmicos viabilizaram a produ??o de ?leo pesado em campos considerados n?o comerciais pelos m?todos convencionais de recupera??o. A inje??o de vapor, em particular, veio a se consagrar ao longo dos anos e ? hoje uma das principais alternativas economicamente vi?vel para o aumento da recupera??o dos ?leos pesados. Dentre as ramifica??es da inje??o de vapor existentes a inje??o c?clica tem sido utilizada com sucesso em escalas comerciais em v?rios pa?ses, incluindo o Brasil. O processo envolve tr?s fases: a primeira ? a inje??o de vapor na qual o vapor ? injetado, dentro do po?o produtor, por um per?odo espec?fico de tempo; em seguida, o po?o ? fechado por um curto per?odo de tempo ( soak period ); e finalmente, o po?o ? recolocado em produ??o durante meses a anos. Esse processo constitui um ciclo. O ciclo ? repetido um n?mero de vezes at? que o limite econ?mico na produ??o seja alcan?ado. Independente do tipo de reservat?rio, a inje??o c?clica geralmente se torna menos eficiente ? propor??o que o n?mero de ciclos aumenta. Este trabalho visa analisar a influ?ncia de algumas propriedades de rocha e reservat?rio na inje??o c?clica de vapor a fim de estudar o n?mero ideal de ciclos e, conseq?entemente, otimizar o processo. Foram realizadas simula??es, utilizando o simulador STARS do grupo CMG, a partir de um modelo de reservat?rio proposto. Observou-se que o efeito da espessura do reservat?rio foi o par?metro que mais influenciou no desempenho do processo, enquanto que para o tempo de soaking essa influ?ncia n?o foi significativa

Im industriellen Bereich erfolgt die Energiebereitstellung auf thermischer, wie elektrischer Seite zunehmend mittels hocheffizienter Kraft-Wärme-Koppelung (KWK). Konventionelle KWK-Anlagen ohne Dampfturbine (DT) verfügen technologiebedingt über eine relativ starre, lastabhängige Stromkennzahl. Damit kann eine wärme- und/oder stromseitige Volatilität schlecht kompensiert werden ohne die jeweils gekoppelte Größe zu beeinflussen. Der integrierte Gas-Dampf-Prozess (GiD-Prozess) zeichnet sich aufgrund der halboffenen Prozessgestaltung durch eine anlagentechnisch sehr einfache Bauweise und damit gegenüber einer klassischen Gas und Dampf-Prozess (GuD)-Anlage geringeren Investitions- und Wartungskosten aus. Die vorliegende Arbeit befasst sich mit der Analyse des lastabhängigen Betriebsverhaltens des integrierter Gas-Dampf-Prozess (GiD)-Prozesses unter Berücksichtigung der Teillastfähigkeit und erreichbarer Lastgradienten. Hierzu werden umfangreiche Versuchsfahrten des Versuchskraftwerks am Zentrum für Energietechnik (ZET) der TU Dresden dargelegt und analysiert. Die Versuche werden durch transiente Systemsimulationen auf Komponentenebene der Kraftwerksanlage nachvollzogen und Erkenntnisse zu dem Effekt der Lastgradienten auf heißgasbeaufschlagte Bauteile gewonnen.

Chemical EOR processes such as polymer flooding and surfactant polymer flooding must be designed and implemented in an economically attractive manner to be perceived as viable oil recovery options. The primary expenses associated with these processes are chemical costs which are predominantly controlled by the crude oil properties of a reservoir. Crude oil viscosity dictates polymer concentration requirements for mobility control and can also negatively affect the rheological properties of a microemulsion when surfactant polymer flooding. High microemulsion viscosity can be reduced with the introduction of an alcohol co-solvent into the surfactant formulation, but this increases the cost of the formulation. Experimental research done as part of this study combined the process of hot water injection with ASP flooding as a solution to reduce both crude oil viscosity and microemulsion viscosity. The results of this investigation revealed that when action was taken to reduce microemulsion viscosity, residual oil recoveries were greater than 90%. Hot water flooding lowered required polymer concentrations by reducing oil viscosity and lowered microemulsion viscosity without co-solvent. Laboratory testing of viscous microemulsions in core floods proved to compromise surfactant performance and oil recovery by causing high surfactant retention, high pressure gradients that would be unsustainable in the field, high required polymer concentrations to maintain favorable mobility during chemical flooding, reduced sweep efficiency and stagnation of microemulsions due to high viscosity from flowing at low shear rates. Rough scale-up chemical cost estimations were performed using core flood performance data. Without reducing microemulsion viscosity, field chemical costs were as high as 26.15 dollars per incremental barrel of oil. The introduction of co-solvent reduced chemical costs to as low as 22.01 dollars per incremental barrel of oil. This reduction in cost is the combined result of increasing residual oil recovery and the added cost of an alcohol co-solvent. Heating the reservoir by hot water flooding resulted in combined chemical and heating costs of 13.94 dollars per incremental barrel of oil. The significant drop in cost when using hot water is due to increased residual oil recovery, reduction in polymer concentrations from reduced oil viscosity and reduction of microemulsion viscosity at a fraction of the cost of co-solvent. / text