Acidizing sandstone reservoirs is a complex process. If not fully studied, it could lead to formation damage. A combination of HCl/HF has been widely used to stimulate sandstone reservoirs. However, the success rate is low due to the complexity of the reactions involved in this process. These reactions result in potentially damaging precipitation and cause formation damage. The problem is more severe when dealing with Bandera sandstone formations that contain a high concentration of carbonate minerals and clay particles. The purpose of this study is to present and evaluate multi-stage acid injection into the Bandera sandstone cores to remove formation damage. In this study, coreflood experiments were conducted on Bandera sandstone cores (1.5 in. x 6 in.) at a flow rate of 4 cm^3/ min and temperature of 140°F. A mixture of formic acid and HF was used as an organic mud acid. Preflush of hydrochloric and formic acid was employed to remove carbonate minerals. Bandera sandstone cores contain a considerable amount of HCl sensitive clays. So another stage was employed to cover clay minerals and prevent HCl attack on the surface of clay particles. Different clay stabilizers as well as preflush pore volume were examined in this study. At the end, this multi-stage treatment design was tested on a Berea sandstone core to investigate the impact of mineralogy. During each experiment effluent samples were collected. Samples were analyzed using Inductively Coupled Plasma (ICP) and Scanning Electron Microscopy (SEM) to investigate reaction kinetics and chemistry of precipitation. Chemical analysis confirmed incompatibility of HCl with clays in Bandera cores at 140°F. Clay stabilizer CSA showed the ability to prevent HCl attack on the clay particle’s surface. As a result, a coreflood experiment conducted using CSA led to permeability improvement. The result of the coreflood experiment conducted using CSC indicated that this chemical is able to exchange cations with clay particles, however permeability decreased due to an insufficient injection of preflush. As in another experiment, increasing preflush pore volume using CSC resulted in permeability improvement. CSB completely failed to cover clay minerals and permeability decreased drastically at the end of the treatment.

Thesis (Ph. D.)--University of Texas at Austin, 2008. / Vita. Includes bibliographical references and index.

[pt] A filtração profunda de suspensões particuladas ocorre em muitos processos industriais e ambientais, como filtração de água e contaminação do solo. Na indústria petrolífera, a filtração profunda ocorre próximo ao poço injetor durante a injeção de água, causando redução de injetividade. A captura de partículas no meio poroso pode ser causada por diferentes mecanismos físicos (exclusão pelo tamanho, forças elétricas, gravidade (sedimentação), etc.). No caso do mecanismo de exclusão pelo tamanho, quanto maiores forem as partículas e menores forem os poros, mais intensa será a captura. Conseqüentemente, maior será o dano à formação. Entretanto, o modelo tradicional não considera as distribuições de tamanho de partículas e de poros. Assumindo que as partículas são capturadas pelo mecanismo de exclusão pelo tamanho, foram deduzidas as equações básicas para o transporte de suspensões particuladas no meio poroso considerando as distribuições de tamanho de poros e de partículas. Apenas o fluxo de água via poros acessíveis transporta partículas, ou seja, as partículas não podem acessar poros menores do que elas. No presente trabalho, os efeitos da redução do fluxo de partículas e da inacessibilidade devido ao fluxo seletivo de diferentes tamanhos de partículas são incluídos no modelo estocástico para a filtração profunda. As soluções analíticas obtidas mostram um comportamento físico mais realístico do que o previsto pelo modelo tradicional. O modelo de medição (concentrações totais) obtido difere substancialmente do modelo tradicional para a filtração profunda. Vários dados experimentais foram tratados, mostrando boa concordância e validando o modelo proposto. Um sistema de equações estocásticas para modelar a formação do reboco externo foi proposto e soluções analíticas foram obtidas, permitindo tratar a filtração profunda e a formação do reboco externo, utilizando o mesmo formalismo matemático. / [en] Deep bed filtration of water with particles occurs in several industrial and environmental processes like water filtration and soil contamination. In petroleum industry, deep bed filtration occurs near to injection wells during water injection, causing injectivity reduction. It also takes place during well drilling, sand production control, produced water disposal in aquifers, etc. The particle capture in porous media can be caused by different physical mechanisms (size exclusion, electrical forces, bridging, gravity (sedimentation), etc.). In case of size exclusion mechanism, the larger are the particles and the smaller are the pores, the more intensive is the capture and the larger is the formation damage. Nevertheless, the widely used traditional model does not account for particle and pore size distributions. Considering that particles are captured due to size exclusion mechanism, we derived basic equations for transport of particulate suspensions in porous media, accounting for particle and pore radii distributions. Particles are carried by water flowing through the accessible pore space only, i.e. particles cannot access smaller pores. In the current work, the effects of porous space accessibility and particle flux reduction due to selective flow of different size particles are included into the stochastic deep bed filtration model. The particle and pore ensembles for analytical solutions of the derived system show more realistic physics behaviour than that of the traditional model. Averaging of the derived stochastic equations leads to a new deep bed filtration model that significantly differs from the classical deep bed filtration system. Treatment of several experimental data shows good agreement between the laboratory and modelling data and validates the proposed model. The derived stochastic model has been extended to model formation of external filter cake by particles from the injected polydispersed suspension, allowing treating both deep bed filtration and external filter cake formation in the framework of the same system of governing equations.

In this thesis, permeability impairment caused by drilling fluids and subsequent cleaning and permeability enhancement by back-flow were investigated by means of experimental and simulation studies. Permeability damage caused by three different drilling fluids was measured experimentally by core tests as a function of the filtration pressure and analyzed using a simulator describing the fines migration and retention in porous media. The pore throat plugging criteria for the three drilling fluids were determined. The particle concentration and the fraction of depositing particles were obtained simultaneously as a function of time and distance along the core length by numerical solution. Simulations were run both with experimental data in forward and backward directions along the core samples. Permeability damage ratio was correlated with respect to drilling filtration pressure specially for each type of the drilling fluids and type curves were constructed. Simulation results accurately match the experimental data, indicating that this simulator can be used for the estimation of permeability reduction, and the permeability and porosity variation along the core samples at various filtration pressures. X-Ray digital image subtraction was applied to different sections of the core plugs before and after the circulation to visualize the fines migration into porous media. The maximum damage ratio was obtained with the CMC added drilling fluid with 81 %. In the absence of CMC and Polymer-XT, the damage ratio was found as 72.8%. It was also determined that a polymer-added drilling fluid characterized with 63.8% permeability damage ratio is the optimum drilling fluid, causing less formation damage than the water-based bentonite mud.

The first main goal of this research is to develop comprehensive analytical and numerical models for the stress distribution around an inclined cased wellbore by considering all wellbore processes and to amend erroneous models of most previous work. The second main goal is to apply the developed models to explain near wellbore phenomena such as cement failure and sand production. To achieve these goals, this work checked the eligibility of using simple elastic approaches for the system by using a poroelastic undrained condition and a steady state condition for stresses induced by wellbore temperature variation. It utilized the generalized plane strain to compensate for the limitation of the plane strain which most previous work had used. In addition, this research developed comprehensive models to improve previous work by using superposing principles. For applying the developed models to cement failure, Mogi-Coulomb criterion for shear failure instead of Mohr-Coulomb and Drucker-Prager criteria was used to properly consider the intermediate stress. Additionally, ABAQUSr was utilized for numerical models with the "model change" option to simulate and combine all individual wellbore processes while MATLABr was used for analytical models. For predicting sand production, fully coupled poroelastic solutions for an inclined open wellbore were modified to obtain the stress distribution around a perforation tunnel after perforating. Then, modified Lade failure criterion was used to calculate the critical drawdown when sand production occurs, that is, when the perforation tunnel starts failure. This research obtained the following results. For developing models, the analytical models improved the previous research. However, the numerical results under a vertical tectonic stress showed discrepancies because of the difference between the generalized plane strain and numerical models. For cement failure, Young's modulus of cement, wellbore pressure and wellbore temperature variation could affect shear failure more significantly than the other factors. The numerical results showed closer to the failure envelopes than the analytical results. For predicting sand production, well completion affected sand production near wellbore and the critical drawdown converged to asymptotic values. In addition, perforating along the minimum horizontal stress direction was most preferable in a vertical cased wellbore under a normal stress regime. / text

Made available in DSpace on 2014-12-17T14:08:46Z (GMT). No. of bitstreams: 1 PedroTPA_DISSERT.pdf: 2026522 bytes, checksum: 77beea38c42704a86dbc6a2648061f42 (MD5) Previous issue date: 2011-07-04 / Stimulation operations have with main objective restore or improve the productivity or injectivity rate in wells. Acidizing is one of the most important operations of well stimulation, consist in inject acid solutions in the formation under fracture formation pressure. Acidizing have like main purpose remove near wellbore damage, caused by drilling or workover operations, can be use in sandstones and in carbonate formations. A critical step in acidizing operation is the control of acid-formation reaction. The high kinetic rate of this reaction, promotes the consumed of the acid in region near well, causing that the acid treatment not achive the desired distance. In this way, the damage zone can not be bypassed. The main objective of this work was obtain stable systems resistant to the different conditions found in field application, evaluate the kinetic of calcite dissolution in microemulsion systems and simulate the injection of this systems by performing experiments in plugs. The systems were obtained from two non ionic surfactants, Unitol L90 and Renex 110, with sec-butanol and n-butanol like cosurfactants. The oily component of the microemlsion was xilene and kerosene. The acqueous component was a solution of HCl 15-26,1%. The results shown that the microemulsion systems obtained were stable to temperature until 100?C, high calcium concentrations, salinity until 35000 ppm and HCl concentrations until 25%. The time for calcite dissolution in microemulsion media was 14 times slower than in aqueous HCl 15%. The simulation in plugs showed that microemulsion systems promote a distributed flux and promoted longer channels. The permeability enhancement was between 177 - 890%. The results showed that the microemulsion systems obtained have potential to be applied in matrix acidizing / As opera??es de estimula??o s?o opera??es realizadas com a finalidade de restaurar ou melhorar o ?ndice de produ??o ou inje??o dos po?os. Dentre as opera??es de estimula??o, destaca-se a opera??o de acidifica??o, que consiste na inje??o de solu??es ?cidas na forma??o, com press?o abaixo da press?o de fratura da forma??o. A acidifica??o tem como principal objetivo remover danos causados nas etapas de perfura??o e/ou workover, podendo ser realizada tanto em arenitos quanto em carbonatos. Um dos pontos mais cr?ticos da opera??o de acidifica??o ? o controle da rea??o ?cido-rocha, pois a elevada velocidade da rea??o faz com que o ?cido seja todo consumido na regi?o pr?xima ao po?o, fazendo com que o tratamento ?cido n?o atinja a dist?ncia desejada. Dessa maneira, as regi?es com dano podem n?o ser ultrapassadas. Este trabalho teve como objetivo obter sistemas microemulsionados est?veis ?s diferentes condi??es encontradas no campo de aplica??o, avaliar a cin?tica de dissolu??o da calcita nesses sistemas, bem como, simular a inje??o desses sistemas realizando ensaios em plugues. Utilizaram-se sistemas microemulsionados obtidos a partir dos tensoativos Renex 110, Unitol L90 e o OMS (?leo de mamona saponificado). Foram utilizandos o sec-butanol e o n-butanol como cotensoativos. Como componentes org?nicos foram utilizados o xileno e o querosene e como componente aquoso foram utilizadas solu??es de HCl variando-se a concentra??o de 15-26,1%. Os resultados mostraram que os sistemas microemulsionados foram est?veis ? temperaturas de at? 100?C, ? concentra??es elevadas de c?lcio, ? salinidade de at? 35000 ppm e a concentra??es de HCl de at? 25%. A cin?tica de dissolu??o da calcita, ao utilizar os sistemas microemulsionados ?cidos, foi at? 14 vezes mais lenta quando comparada com a solu??o de HCl 15%. Os resultados da inje??o dos sistemas ?cidos mostraram que as microemuls?es favorecem um fluxo mais distribu?do com rela??o ao HCl 15%, bem como, formam canais mais longos, promovendo incrementos na permeabilidade dos plugues de 177 - 890%. Os resultados mostraram que os sistemas microemulsionados possuem potencial para aplica??o em opera??es de acidifica??o de po?os

Made available in DSpace on 2014-12-17T14:08:32Z (GMT). No. of bitstreams: 1 PauloHLB.pdf: 2469292 bytes, checksum: ffc7ae61ceea8c4e2281f69274f4d8c7 (MD5) Previous issue date: 2008-12-12 / Deep bed filtration occurs in several industrial and environmental processes like water filtration and soil contamination. In petroleum industry, deep bed filtration occurs near to injection wells during water injection, causing injectivity reduction. It also takes place during well drilling, sand production control, produced water disposal in aquifers, etc. The particle capture in porous media can be caused by different physical mechanisms (size exclusion, electrical forces, bridging, gravity, etc). A statistical model for filtration in porous media is proposed and analytical solutions for suspended and retained particles are derived. The model, which incorporates particle retention probability, is compared with the classical deep bed filtration model allowing a physical interpretation of the filtration coefficients. Comparison of the obtained analytical solutions for the proposed model with the classical model solutions allows concluding that the larger the particle capture probability, the larger the discrepancy between the proposed and the classical models / A filtra??o profunda de suspens?es particuladas ocorre em muitos processos industriais e ambientais, como filtra??o de ?gua e contamina??o do solo. Na ind?stria petrol?fera, a filtra??o profunda ocorre pr?ximo ao po?o injetor durante a inje??o de ?gua, causando redu??o de injetividade. Este processo tamb?m ocorre durante a perfura??o de po?os de petr?leo, o controle da produ??o de areia, o descarte de ?gua produzida em aq??feros, etc. A captura de part?culas no meio poroso pode ser causada por diferentes mecanismos f?sicos (exclus?o pelo tamanho, for?as el?tricas, gravidade, etc.). Neste trabalho, um modelo estat?stico para a filtra??o em meios porosos ? proposto e solu??es anal?ticas para as concentra??es de part?culas em suspens?o e retidas s?o obtidas. O modelo, que incorpora a probabilidade de captura de part?culas, foi comparado com o modelo cl?ssico permitindo uma interpreta??o f?sica dos coeficientes de filtra??o. As solu??es anal?ticas encontradas para o modelo proposto foram comparadas com a modelagem cl?ssica, mostrando que quanto maior a probabilidade de captura de part?culas durante o transporte em meios porosos, maior ? a discrep?ncia entre a modelagem cl?ssica e o modelo proposto

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

Made available in DSpace on 2014-12-17T14:08:53Z (GMT). No. of bitstreams: 1 AdrianoJAMB_DISSERT.pdf: 6352547 bytes, checksum: 4f7f1e181e2f04659c084a8901764e58 (MD5) Previous issue date: 2012-07-13 / Injectivity decline, which can be caused by particle retention, generally occurs during water injection or reinjection in oil fields. Several mechanisms, including straining, are responsible for particle retention and pore blocking causing formation damage and injectivity decline. Predicting formation damage and injectivity decline is essential in waterflooding projects. The Classic Model (CM), which incorporates filtration coefficients and formation damage functions, has been widely used to predict injectivity decline. However, various authors have reported significant discrepancies between Classical Model and experimental results, motivating the development of deep bed filtration models considering multiple particle retention mechanisms (Santos & Barros, 2010; SBM). In this dissertation, inverse problem solution was studied and a software for experimental data treatment was developed. Finally, experimental data were fitted using both the CM and SBM. The results showed that, depending on the formation damage function, the predictions for injectivity decline using CM and SBM models can be significantly different / A perda de injetividade, que pode ser causada pela reten??o de part?culas, ocorre geralmente durante a inje??o ou reinje??o de ?gua em campos de petr?leo. V?rios mecanismos, incluindo a exclus?o pelo tamanho (straining), s?o respons?veis pela reten??o de part?culas e bloqueio dos poros da forma??o, causando dano e o decl?nio da injetividade. A previs?o para o dano ? forma??o e a queda da injetividade ? essencial para o gerenciamento de projetos de inje??o de ?gua. O modelo cl?ssico (MC), que incorpora os coeficientes de filtra??o e de dano ? forma??o, tem sido amplamente utilizado na previs?o da perda de injetividade. Esse modelo apresenta bons resultados quando apenas um mecanismo de reten??o ? atuante. Entretanto, v?rios autores relataram discrep?ncias significativas entre o modelo cl?ssico e os dados experimentais, motivando o desenvolvimento de modelos que consideram m?ltiplos mecanismos de reten??o de part?culas, como o modelo de Santos e Barros (MSB, 2010). Neste trabalho, foi estudada a solu??o do problema inverso para diferentes modelos. A partir deste estudo, foi desenvolvido um software para o tratamento dos dados experimentais. Finalmente, os dados experimentais foram ajustados usando tanto o MC quanto o MSB. Os resultados demonstraram que, dependendo da fun??o dano ? forma??o utilizada, as previs?es dos modelos MC e MSB para a perda de injetividade podem ser significativamente diferentes