Relevant bibliographies by topics / Geomechanical model

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  2. Dissertations / Theses
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Academic literature on the topic 'Geomechanical model'

Author: Grafiati
Published: 4 June 2021
Last updated: 16 February 2022

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Journal articles on the topic "Geomechanical model"

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Kim, Guan Woo, Tae Hong Kim, Jiho Lee, and Kun Sang Lee. "Coupled Geomechanical-Flow Assessment of CO2 Leakage through Heterogeneous Caprock during CCS." Advances in Civil Engineering 2018 (2018): 1–13. http://dx.doi.org/10.1155/2018/1474320.

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The viability of carbon capture sequestration (CCS) is dependent on the secure storage of CO2 in subsurface geologic formations. Geomechanical failure of caprock is one of the main reasons of CO2 leakage from the storage formations. Through comprehensive assessment on the petrophysical and geomechanical heterogeneities of caprock, it is possible to predict the risk of unexpected caprock failure. To describe the fracture reactivation, the modified Barton–Bandis model is applied. In order to generate hydro-geomechanically heterogeneous fields, the negative correlation between porosity and Young’s modulus/Poisson’s ratio is applied. In comparison with the homogeneous model, effects of heterogeneity are examined in terms of vertical deformation and the amount of leaked CO2. To compare the effects of heterogeneity, heterogeneous models for both geomechanical and petrophysical properties in coupled simulation are designed. After 10-year injection with petrophysically heterogeneous and geomechanically homogeneous caprock, CO2 leakage is larger than that of the homogeneous model. In contrast, heterogeneity of geomechanical properties is shown to mitigate additional escape of CO2. Vertical displacement of every heterogeneous model is larger than homogeneous model. The model with compressive tectonic stress shows much more stable trapping with heterogeneous caprock, but there is possibility of rapid leakage after homogeneous caprock failure.
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Azad, A., and R. J. J. Chalaturnyk. "The Role of Geomechanical Observation in Continuous Updating of Thermal-Recovery Simulations With the Ensemble Kalman Filter." SPE Journal 18, no. 06 (May 29, 2013): 1043–56. http://dx.doi.org/10.2118/146898-pa.

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Summary In-situ thermal methods such as steam-assisted gravity drainage (SAGD) and cyclic steam stimulation (CSS) are widely used in oil-sand reservoirs. The physics of such thermal processes is generally well-understood, and it has been shown that rock properties are highly influenced by the geomechanical behavior of the reservoir during these recovery processes. Geomechanics improves the process dynamically, and its response can depict the progress of production within a reservoir. However, the potential of geomechanical monitoring is not usually practiced. With increased implementation of highly instrumented wells and communication technologies providing real-time monitoring data from different sources, combining available data into reservoir geomechanical simulations can improve updating numerical models and the prediction process. This research explores effective uses of geomechanical observation data for history matching and types of geomechanical observation sources adequate for thermal recovery. The ensemble Kalman filter (EnKF), combined with an iterative geomechanical coupled simulator, has been chosen as the data-assimilation algorithm to update the model continuously on the basis of geomechanical observations and production data. The results show that considering geomechanical modeling and observation improves history matching when geomechanical behavior plays a role in the process.
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Sharifi, Javad, Naser Hafezi Moghaddas, Gholam Reza Lashkaripour, Abdolrahim Javaherian, and Marzieh Mirzakhanian. "Application of extended elastic impedance in seismic geomechanics." GEOPHYSICS 84, no. 3 (May 1, 2019): R429—R446. http://dx.doi.org/10.1190/geo2018-0242.1.

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We have evaluated an innovative application of extended elastic impedance (EEI) to integrate seismic and geomechanics for geomechanical interpretation of hydrocarbon reservoirs. EEI analysis is used to extract geomechanical parameters. To verify and assess the capabilities of EEI analysis for extracting geomechanical parameters, we selected a jointed, oil-bearing, shale carbonate reservoir in the southwest of Iran, and we used petrophysical data and core analysis to estimate static and dynamic moduli of the reservoir rock. We calculated the corresponding EEI curve to different intercept-gradient coordinate rotation angles (the chi angle, [Formula: see text]), and we selected the angles of the maximum correlation for the corresponding geomechanical parameters. Then, combining the intercept and gradient, we generated 3D reflectivity patterns of EEI at different angles. To obtain a cube of geomechanical parameters, we performed model-based inversion on the EEI reflectivity pattern. A comparison between the modeling results and well data indicated that the geomechanical parameters estimated by our method were well-correlated to the observed data. Accordingly, we extracted the geomechanical and rock-physical parameters from the EEI cube. We further found that EEI analysis was capable of giving a 3D mechanical earth model of the reservoir with the appropriate accuracy. Finally, we verified the proposed methodology on a blind well and compared the results with those of the simultaneous inversion, indicating comparable levels of accuracy. Therefore, application of this method in seismic geomechanics can bring about significant progress in the future.
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ZHANG, SHIKE, YUAN YUAN, JIANQING XIAO, and SHUNDE YIN. "APPLICATION OF COMPUTATIONAL INTELLIGENCE METHOD IN PETROLEUM GEOMECHANICS CHARACTERIZATION." International Journal of Computational Intelligence and Applications 13, no. 04 (December 2014): 1450021. http://dx.doi.org/10.1142/s1469026814500217.

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Petroleum geomechanics characterization refers to the process of quantitatively assigning geomechanical parameters using all available field data. In this paper, an attempt is made to develop a computational intelligence method that integrates genetic algorithm (GA) and artificial neural network (ANN). Through this method, these geomechanical parameters such as horizontal in situ stresses, fracture aperture and joint spacing are determined based on the borehole displacements during drilling well. In the hybrid ANN–GA model, GA can automatically identify geomechanical parameters as neural inputs from monitored borehole displacements, and the ANN is trained to learn the complex relationship between geomechanical parameters and target borehole displacements. Data from numerical experiments on petroleum wells are used in verification of the proposed computational intelligence method for geomechanics characterization. The study of numerical experiment illustrates that the proposed computational intelligence method has the ability to generate reliable results.
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Younessi, Ahmadreza. "Where, when and how a field-scale 4D geomechanical model should be built." APPEA Journal 57, no. 2 (2017): 814. http://dx.doi.org/10.1071/aj16211.

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Analytical approaches have been successfully used for decades to analyse different geomechanical related problems in the oil and gas industry. These approaches are still applicable for most problems. However, they may not be suitable for complex environments that the industry is increasingly facing nowadays. The challenges to develop complex fields require the industry to have a better understanding and prediction of the behaviour of reservoir rocks and their overburden formations during field production. This can be partially achieved by conducting a more comprehensive analysis by means of numerical methods in a wider scale of space and time. We refer to this as 4D geomechanical modelling. The concept of 4D geomechanical modelling is relatively new in the industry, and there is limited knowledge regarding the applications and advantages of this type of modelling within disciplines other than geomechanics. It is essential to understand in which type of reservoirs and at what stage of development this type of modelling should be considered. Here in this manuscript, after discussing these considerations, the techniques and procedures to build and interpret a 4D geomechanical model are discussed.
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Ahmed, Barzan I., and Mohammed S. Al-Jawad. "Geomechanical modelling and two-way coupling simulation for carbonate gas reservoir." Journal of Petroleum Exploration and Production Technology 10, no. 8 (August 10, 2020): 3619–48. http://dx.doi.org/10.1007/s13202-020-00965-7.

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Abstract Geomechanical modelling and simulation are introduced to accurately determine the combined effects of hydrocarbon production and changes in rock properties due to geomechanical effects. The reservoir geomechanical model is concerned with stress-related issues and rock failure in compression, shear, and tension induced by reservoir pore pressure changes due to reservoir depletion. In this paper, a rock mechanical model is constructed in geomechanical mode, and reservoir geomechanics simulations are run for a carbonate gas reservoir. The study begins with assessment of the data, construction of 1D rock mechanical models along the well trajectory, the generation of a 3D mechanical earth model, and running a 4D geomechanical simulation using a two-way coupling simulation method, followed by results analysis. A dual porosity/permeability model is coupled with a 3D geomechanical model, and iterative two-way coupling simulation is performed to understand the changes in effective stress dynamics with the decrease in reservoir pressure due to production, and therefore to identify the changes in dual-continuum media conductivity to fluid flow and field ultimate recovery. The results of analysis show an observed effect on reservoir flow behaviour of a 4% decrease in gas ultimate recovery and considerable changes in matrix contribution and fracture properties, with the geomechanical effects on the matrix visibly decreasing the gas production potential, and the effect on the natural fracture contribution is limited on gas inflow. Generally, this could be due to slip flow of gas at the media walls of micro-extension fractures, and the flow contribution and fracture conductivity is quite sufficient for the volume that the matrixes feed the fractures. Also, the geomechanical simulation results show the stability of existing faults, emphasizing that the loading on the fault is too low to induce fault slip to create fracturing, and enhanced permeability provides efficient conduit for reservoir fluid flow in reservoirs characterized by natural fractures.
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Wang, Wenli, Julia Diessl, and Michael S. Bruno. "Surface deformation study for a geothermal operation field." Advances in Geosciences 45 (September 4, 2018): 243–49. http://dx.doi.org/10.5194/adgeo-45-243-2018.

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Abstract. GeoMechanics Technologies has investigated the surface deformation that occurred at a geothermal field operation located in New Zealand. The thermal area associated with this field has extensive surface infrastructures that are in close proximity to a lake. Geothermal operations initially began in 1997 while surface subsidence has been observed since early 2004. We were contracted by the client to review and analyze the impact of future development plans on ground level changes in hopes to mitigate further compaction and subsidence in the area. There is significant concern that continued surface subsidence may cause the lake to flood the surrounding area. An integrated 3-D geological model, geomechanical model, and fluid and heat flow model were developed for this study. To ensure accuracy, a history match and calibration was performed on the geomechanical model using historical subsidence survey data and on the fluid and heat flow simulation using historical injection and production data. The calibrated geomechanical model was then applied to simulate future scenarios to predict surface subsidence and provide a guideline to optimize field development plans.
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Hosseini, Behrooz Koohmareh, and Rick Chalaturnyk. "A Domain Splitting-Based Analytical Approach for Assessing Hydro-Thermo-Geomechanical Responses of Heavy-Oil Reservoirs." SPE Journal 22, no. 01 (July 28, 2016): 300–315. http://dx.doi.org/10.2118/170193-pa.

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Summary For stress-sensitive heavy-oil reservoirs, geomechanical responses of the reservoir are taken into account because they play an important role in the accurate simulation of all thermal recovery techniques, such as steam-assisted gravity drainage (SAGD) or steamflood. However, full-field numerical simulations of multiphysics processes by any coupling strategies are technically impossible with current computer central processing units (CPUs). Under these conditions, analytical methods can be used as approximate techniques instead of numerical simulators because they are much faster and yet are useful tools for preliminary forecasting and sensitivity studies. In analytical models, inclusion of all flow-variable impacts into geomechanics frameworks make the equations complex and almost impossible to solve. This paper provides a flow-based domain decomposition work flow for performing different analytical coupling schemes in different reservoir compartments. Because the intensity and complexity of reservoir geomechanics vary over reservoir domain, one can divide the reservoir to some subdomains and assess different geomechanical responses separately in each subdomain. The presented analytical proxy suggests decomposition of the entire domain into two parts of “heated zone” and “wetted zone,” for rapid assessment of geomechanics. The heat-flow equation was combined with mass and momentum convective-transport equations to obtain an exact approach that correlates the saturation front of injected hot water to temperature front. The frontal velocities are dynamic interfaces for compartmentalization of the domain. In the heated zone, the total induced stresses were considered because both temperature and pressure increase, and in the wetted (saturated) zone beyond the temperature front, at each instance, the total stress induced is only a function of pressure increase, and, accordingly, stress and strain induced are caused by isotropic unloading. This technique provides a rapid estimate of geomechanical responses (stress and strain profile) in each part of the reservoir (near field and far field). A numerical model was built and implemented in CMG-STARS for a steamflood case to show the robustness and applicability range of the model. The results were analyzed for a synthetic-case single-domain model, and the model sensitivity on some reservoir parameters was checked, while geomechanical responses were not neglected anywhere (near field and far field) in the reservoir. The results of the numerical model were in close agreement with the result of the proposed analytical proxy.
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Huang, Jian, Reza Safari, Uno Mutlu, Kevin Burns, Ingo Geldmacher, Mark McClure, and Stuart Jackson. "Natural-hydraulic fracture interaction: Microseismic observations and geomechanical predictions." Interpretation 3, no. 3 (August 1, 2015): SU17—SU31. http://dx.doi.org/10.1190/int-2014-0233.1.

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Natural fractures can reactivate during hydraulic stimulation and interact with hydraulic fractures producing a complex and highly productive natural-hydraulic fracture network. This phenomenon and the quality of the resulting conductive reservoir area are primarily functions of the natural fracture network characteristics (e.g., spacing, height, length, number of fracture sets, orientation, and frictional properties); in situ stress state (e.g., stress anisotropy and magnitude); stimulation design parameters (e.g., pumping schedule, the type/volume of fluid[s], and proppant); well architecture (number and spacing of stages, perforation length, well orientation); and the physics of the natural-hydraulic fracture interaction (e.g., crossover, arrest, reactivation). Geomechanical models can quantify the impact of key parameters that control the extent and complexity of the conductive reservoir area, with implications to stimulation design and well optimization in the field. We have developed a series of geomechanical simulations to predict natural-hydraulic fracture interaction and the resulting fracture network in complex settings. A geomechanics-based sensitivity analysis was performed that integrated key reservoir-geomechanical parameters to forward model complex fracture network generation, synthetic microseismic (MS) response, and associated conductivity paths as they evolve during stimulation operations. The simulations tested two different natural-hydraulic fracture interaction scenarios and could generate synthetic MS events. The sensitivity analysis revealed that geomechanical models that involve complex fracture networks can be calibrated against MS data and can help to predict the reservoir response to stimulation and optimize the conductive reservoir area. We analyzed a field data set (obtained from two hydraulically fractured wells in the Barnett Formation, Tarrant County, Texas) and established a coupling between the geomechanics and MS within the framework of a 3D geologic model. This coupling provides a mechanics-based approach to (1) verify MS trends and anomalies in the field, (2) optimize conductive reservoir area for reservoir simulations, and (3) improve stimulation design on the current well in near-real-time and well design/stimulation for future wells.
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Schutjens, P. M. T. M. M. T. M., J. R. R. Snippe, H. Mahani, J. Turner, J. Ita, and A. P. P. Mossop. "Production-Induced Stress Change in and Above a Reservoir Pierced by Two Salt Domes: A Geomechanical Model and Its Applications." SPE Journal 17, no. 01 (October 25, 2011): 80–97. http://dx.doi.org/10.2118/131590-pa.

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Summary Production decreases the pore-fluid pressure and increases the effective stress acting on the load-bearing-grain framework that makes up the reservoir. As a result, the reservoir deforms and compacts, and because it is connected to the rocks around it, there will be deformations and displacements in these rocks also. Well known geomechanical effects of production include surface subsidence, wells damaged by shear, and time shifts in 4D seismic. Less well known is how the changes in the stress field itself should be taken into account in operations—e.g., to design infill wells and to plan production stimulation by hydraulic fracturing or waterflooding of the reservoir. We present a geomechanical model for the initial stress field and production-induced stress changes in and around a steeply dipping hydrocarbon reservoir penetrated by two large salt domes. The model integrates 3D seismic and geological understanding, geomechanical data from wells and analogues, and depletion patterns from fluid-flow (dynamic) simulation. Our model results confirm published models of principal-stress orientation in rocks pierced by salt domes. The depleted-model results show stress changes up to several MPa in magnitude compared with the preproduction stress state, but only limited changes in the stress orientations. The model highlights the influence of structural dip and time-dependent salt/sediment interaction on stress changes. We then describe the application of the model in wellbore stress analysis for infill wells and in a water-injection scheme that has, we believe, been severely impacted by injection-induced fractures propagating in the reservoir from the injector wells toward the producer wells. We explain how the latter application uses a 3D flow-simulation model coupled to a dynamic fracture-propagation model. The geomechanical model provides key input: stress magnitude and stress orientation. Results are validated against a more conventional analysis of real-time pressure data. In both applications, the integration of geomechanics in 3D static and dynamic models improved insight into the rock response to drilling and waterflooding, thus helping to optimize production.
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Dissertations / Theses on the topic "Geomechanical model"

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Martínez, Montesinos Beatriz [Verfasser]. "Numerical approaches to model and monitor geomechanical reservoir integrity / Beatriz Martínez Montesinos." Mainz : Universitätsbibliothek Mainz, 2019. http://d-nb.info/1188573861/34.

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ARGOTE, SANDRA MILENA ROSERO. "GEOMECHANICAL MODEL APPLIED TO THE STABILITY ANALYSIS OF WELLS WITH ENPHASIS ON SHALES." PONTIFÍCIA UNIVERSIDADE CATÓLICA DO RIO DE JANEIRO, 2012. http://www.maxwell.vrac.puc-rio.br/Busca_etds.php?strSecao=resultado&nrSeq=21833@1.

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PONTIFÍCIA UNIVERSIDADE CATÓLICA DO RIO DE JANEIRO
COORDENAÇÃO DE APERFEIÇOAMENTO DO PESSOAL DE ENSINO SUPERIOR
Frente à crescente complexidade dos cenarios de exploração de petróleo, as análises de estabilidade convencionais tornam-se insuficientes para determinar as condições reais dos poços. Assim, ciente destas limitações, a indústria do petróleo vem aplicando com mais frequência novos métodos como o modelo geomecânico denominado Mechanical Earth Model (MEM), pois permite gerar uma previsão da estabilidade do poço e ajuda a reduzir os riscos de perfuração. Neste sentido, o presente trabalho apresenta uma metodologia para estimar as condições da estabilidade de poços com ênfase nas formações de folhelhos, através da identificação e análise de problemas e eventos que revelem sinais de instabilidade geomecânica levantados nos dados de perfuração disponíveis. Boletins diários de perfuração e perfis elétricos de poços são as fontes de dados para análise de problemas de estabilidade que são os responsáveis pela maior parte dos tempos não produtivos, e consequentemente, de custos extras de perfuração. Por tanto, o estudo e o entendimento destes problemas contribuirá para a otimização do processo de perfuração, melhorando assim as práticas ou mitigando os efeitos severos das anormalidades.
Facing the increasing complexity of scenarios for oil exploration, the conventional stability analysis became insufficient to determine the actual condition of the wells. Aware of these limitations, the oil industry has been applying new methods such as the geomechanical model named Mechanical Earth Model – MEM, which has been applied on the prediction of wellbore stability and drilling risks mitigation. In this sense, this work presents a methodology for estimating the wellbore stability conditions of wells with special emphasis on shale formations, through the identification and assessment of events which indicate geomechanical instability during drilling. These data are available from daily drilling reports and electric logs. Well Stability problems are responsible for most non-productive time, and consequently, the extra drilling costs. Therefore, the study and understanding of these problems contribute to the drilling optimization, thus improving the practices or mitigating the effects of severe abnormalities.
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Ramiah, Kalidhasen. "2D Geomechanical Model for an Offshore Gas Field in the Bredasdorp Basin, South Africa." University of the Western Cape, 2016. http://hdl.handle.net/11394/5863.

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Magister Scientiae - MSc (Earth Science)
This thesis provides a 2D geomechanical model for the K-R field, Bredasdorp Basin and describes the workflow and process to do so. This study has a unique density correction software applied to density data, prior to the estimation of geopressure gradients. The aim of this research is to create a model that evaluates the geomechanical behaviour of the upper shallow marine reservoir (USM) and provide a safe drilling mud window for future in the area.
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Morgan, William Edmund. "A fully implicit stochastic model for hydraulic fracturing based on the discontinuous deformation analysis." Diss., Georgia Institute of Technology, 2014. http://hdl.handle.net/1853/53073.

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In recent years, hydraulic fracturing has led to a dramatic increase in the worldwide production of natural gas. In a typical hydraulic fracturing treatment, millions of gallons of water, sand and chemicals are injected into a reservoir to generate fractures in the reservoir that serve as pathways for fluid flow. Recent research has shown that both the effectiveness of fracturing treatments and the productivity of fractured reservoirs can be heavily influenced by the presence of pre-existing natural fracture networks. This work presents a fully implicit hydro-mechanical algorithm for modeling hydraulic fracturing in complex fracture networks using the two-dimensional discontinuous deformation analysis (DDA). Building upon previous studies coupling the DDA to fracture network flow, this work emphasizes various improvements made to stabilize the existing algorithms and facilitate their convergence. Additional emphasis is placed on validation of the model and on extending the model to the stochastic characterization of hydraulic fracturing in naturally fractured systems. To validate the coupled algorithm, the model was tested against two analytical solutions for hydraulic fracturing, one for the growth of a fixed-length fracture subject to constant fluid pressure, and the other for the growth of a viscosity-storage dominated fracture subject to a constant rate of fluid injection. Additionally, the model was used to reproduce the results of a hydraulic fracturing experiment performed using high-viscosity fracturing fluid in a homogeneous medium. Very good agreement was displayed in all cases, suggesting that the algorithm is suitable for simulating hydraulic fracturing in homogeneous media. Next, this work explores the relationship between the maximum tensile stress and Mohr-Coulomb fracture criteria used in the DDA and the critical stress intensity factor criteria from linear elastic fracture mechanics (LEFM). The relationship between the criteria is derived, and the ability of the model to capture the relationship is examined for both Mode I and Mode II fracturing. The model was then used to simulate the LEFM solution for a toughness-storage dominated bi-wing hydraulic fracture. Good agreement was found between the numerical and theoretical results, suggesting that the simpler maximum tensile stress criteria can serve as an acceptable substitute for the more rigorous LEFM criteria in studies of hydraulic fracturing. Finally, this work presents a method for modeling hydraulic fracturing in reservoirs characterized by pre-existing fracture networks. The ability of the algorithm to correctly model the interaction mechanism of intersecting fractures is demonstrated through comparison with experimental results, and the method is extended to the stochastic analysis of hydraulic fracturing in probabilistically characterized reservoirs. Ultimately, the method is applied to a case study of hydraulic fracturing in the Marcellus Shale, and the sensitivity of fracture propagation to variations in rock and fluid parameters is analyzed.
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FILHO, ARMANDO PRESTES DE MENEZES. "THERMODYNAMIC NONEXTENSIVITY, DISCRETE SCALE INVARIANCE AND ELASTOPLASTICITY: A STUDY OF A SELF-ORGANIZED CRITICAL GEOMECHANICAL NUMERICAL MODEL." PONTIFÍCIA UNIVERSIDADE CATÓLICA DO RIO DE JANEIRO, 2003. http://www.maxwell.vrac.puc-rio.br/Busca_etds.php?strSecao=resultado&nrSeq=4249@1.

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PONTIFÍCIA UNIVERSIDADE CATÓLICA DO RIO DE JANEIRO
Esta tese busca utilizar os novos conceitos físicos relacionados à física do estado sólido e à mecânica estatística - teoria do caos e geometria fractal - na análise do comportamento de sistemas dinâmicos não-lineares. Mais pormenorizadamente, trata-se de estudar o comportamento de um modelo numérico elasto-plástico com função de escoamento de Mohr-Coulomb, usualmente empregado em simulações de materiais geológicos - cimentados ou não -, quando submetido a carregamentos externos, situação esta geralmente encontrada em problemas afeitos à mecânica dos solos e das rochas (p/ex., estabilidade de taludes e escavações subterrâneas). Mostra-se que tal modelo geomecânico de muitos corpos (many-body) interagentes é conduzido espontaneamente, ao longo de sua evolução temporal, à chamada criticalidade auto-organizada (self- organized criticality - SOC), estado caracterizado por apresentar evolução na fronteira entre ordem e caos, sensibilidade extrema a qualquer pequena perturbação, e desenvolvimento de interações espaço-temporais de longo alcance. Como a evolução de qualquer sistema dinâmico pode ser vista como um fluxo ininterrupto de informações entre suas partes constituintes, avaliou-se, para tal sistema, a entropia de Tsallis, formulação original proposta pelo físico brasileiro Constantino Tsallis, do Centro Brasileiro de Pesquisas Físicas (CBPF), tendo se mostrado adequada à sua descrição. Em especial, determinou-se para tal sistema, pela primeira vez, o valor do índice entrópico, que parametriza a aludida forma entrópica alternativa. Ademais, como é característico de sistemas fora do equilíbrio regidos por uma dinâmica de limiar, mostra-se que tal sistema geomecânico, durante o seu desenvolvimento, teve a sua simetria translacional inicial quebrada, sendo substituída pela simetria por escala, auto-semelhante (i.é., fractal). Em decorrência, o modelo exibe a chamada invariância discreta de escala (discrete scale invariance - DSI), fruto do processo mesmo de ruptura progressiva do material heterogêneo. Especificamente, as simulações numéricas sugeriram que o processo de ruptura progressiva do material elasto-plástico se dá por uma transferência multiplicativa de tensões, em diferentes escalas de observação hierarquicamente dispostas, acarretando o aparecimento de sinais bastante peculiares, caracterizados por desvios oscilatórios sistemáticos do padrão em lei de potência, o que possibilita a previsão de sua ruína, quando ainda em fase preparatória. Assim, esta pesquisa mostrou a eficiência de tal método de previsão, aplicado, pela primeira vez, não somente aos resultados das simulações numéricas do referido modelo geomecânico, como aos ensaios de laboratório em rochas sedimentares, realizados no Centro de Pesquisas da Petrobrás (CENPES). Por fim, é interessante assinalar que o material elasto-plástico investigado neste trabalho teve seu comportamento compartilhado por um modelo matemático bastante simples, fundamentado na função binomial multifractal, reconhecida por descrever processos multiplicativos em diferentes escalas.
This thesis aims at applying new concepts from solid state physics and statistical mechanics - chaos theory and fractal geometry - to the study of nonlinear dynamic systems. More precisely, it deals with a two-dimensional continuum elastoplastic Mohr-Coulomb model, commonly used to simulate pressure-sensitive materials (e.g., soils, rocks and concrete) subjected to stress-strain fields, normally found in general soil or rock mechanics problems (e.g., slope stability and underground excavations). It is shown that such many-body system is spontaneously driven to a state at the edge of chaos, called self- organized criticality (SOC), capable of developing long- range interactions in space and long-range memory in time. A new entropic form proposed by C. Tsallis is presented and shown that it is the suitable theoretical framework to deal with these problems. Furthermore, the index q of the Tsallis entropy, which measures the degree of non- additivity of the system, is calculated, for the first time, for an elastoplastic model. In addition, as is usual in non-equilibrium systems with threshold dynamics, the model changes its symmetry, from translational to fractal (that is, self-similar), leading to what is called discrete scale invariance. It is shown that this special type of scale invariance, characterized by systematic oscillatory deviations from the fundamental power-law behavior, can be used to predict the failure of heterogeneous materials, while the process is still being build-up, i.e., from precursory signals, typical of progressive failure processes. Specifically, this framework was applied, for the first time, not only to the elastoplastic geomechanical model, but to laboratory tests in sedimentary rocks as well. Finally, it is interesting to realize that the above- mentioned behaviors are also displayed by the binomial multifractal function, known to adequately describe multiplicative cascading processes.
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Hekmatnejad, Amin. "Geostatistical modeling of discrete fracture networks for geomechanical applications in heterogeneous fractured media based on the cox-boolean model." Tesis, Universidad de Chile, 2018. http://repositorio.uchile.cl/handle/2250/167753.

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Doctor en Ingeniería de Minas
La caracterización de fracturas es crítica en minería a cielo abierto y subterránea, así como en ingeniería geológica e ingeniería de petróleo, para comprender las propiedades mecánicas e hidráulicas del macizo rocoso. Dado que se observa una fracción muy pequeña de las fracturas en un área de estudio, no es aconsejable un modelo determinístico de la red de fracturas y, a menudo, es preferible un modelo estocástico. Esta tesis se centra en el llamado modelo Cox-Booleano de discos planos para describir redes de fracturas discretas, que se basa en la definición de un proceso puntual de Cox que representa los centros de fracturas, así como en una distribución de las orientaciones y de los diámetros de fracturas. El problema específico abordado es la inferencia de los parámetros del modelo, basada en información de muestreo 1D o 2D que se origina a partir de sondajes, observaciones en líneas o bidimensionales. Las soluciones actuales al problema de inferencia suelen ser aproximadas o incipientes, especialmente en lo que se refiere al potencial del proceso de Cox subyacente, que consiste en un campo aleatorio que modela el número promedio de centros de fracturas por unidad de volumen del macizo rocoso. Se desarrollan tres métodos para modelar los parámetros de un modelo Cox-Booleano. El primero se centra en la estimación de la distribución de diámetros de fracturas en función de la distribución de longitudes de trazas determinadas a partir de observaciones areales. El segundo método aborda el problema de predecir espacialmente la intensidad de fracturas (P32) y cuantificar la incertidumbre en los valores verdaderos de P32, utilizando la información de las discontinuidades observadas a lo largo de sondajes. El tercer método permite inferir la distribución del potencial en base a la intensidad de fracturas como una variable auxiliar y a una identidad general entre las distribuciones de diámetros de fracturas, de la intensidad de fracturas y del campo potencial sobre un soporte de bloque grande. Las herramientas y métodos propuestos se aplican a estudios de casos sintéticos y reales para demostrar su aplicabilidad. El conocimiento de los parámetros del modelo abre el camino para simular el DFN en el espacio y condicionar la simulación a datos observados.
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7

De, Laplante Neil Edward James. "A framework for comparing geomechanical models of InSAR-measured surface deformation." Thesis, Massachusetts Institute of Technology, 2011. http://hdl.handle.net/1721.1/69473.

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Thesis (S.M.)--Massachusetts Institute of Technology, Dept. of Earth, Atmospheric, and Planetary Sciences, 2011.
Cataloged from PDF version of thesis.
Includes bibliographical references (p. 133-137).
High-quality Interferometric Synthetic Aperture Radar (InSAR) surface deformation data for field sites around the world has become widely available over the past decade. Geomechanical models based on InSAR data occur frequently in the literature but few methods of systematically optimizing or comparing them are presented. This work discusses parameterization errors for simplified models of strike-slip, normal, thrust and reservoir-style faulting with the aim of identifying tests or characteristics that can differentiate between error types uniquely. Fault dip errors, slip errors and depth errors are modelled using a simple homogeneous elastic half-space earth model. Simple difference maps prove to be a powerful tool for identifying error types and parameter sensitivity, with gradient maps and gradient difference maps useful for distinguishing between similar cases. The fault dip proves to be more indicative of error resolving capability than the faulting regime; errors on intermediately dipping faults are very difficult to differentiate. More detailed modelling of compound errors, complex geomechanical properties and noisy data is proposed. The use of the tests as the starting point for an artificially intelligent modelling package is briefly discussed.
by Neil Edward James de Laplante.
S.M.
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8

Mohamed, Ahmad. "Multi-physics modeling of geomechanical systems with coupled hydromechanical behaviors." Master's thesis, University of Central Florida, 2013. http://digital.library.ucf.edu/cdm/ref/collection/ETD/id/5674.

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Geotechnical structures under realistic field conditions are usually influenced with complex interactions of coupled hydromechanical behavior of porous materials. In many geotechnical applications, however, these important coupled interactions are ignored in their constitutive models. Under coupled hydromechanical behavior, stress in porous materials causes volumetric change in strain, which causes fluid diffusion; consequently, pore pressure dissipates through the pores that results in the consolidation of porous material. The objective of this research was to demonstrate the advantages of using hydromechanical models to estimate deformation and pore water pressure of porous materials by comparing with mechanical-only models. Firstly, extensive literature survey was conducted about hydro-mechanical models based on Biot's poroelastic concept. Derivations of Biot's poroelastic equations will be presented. To demonstrate the hydromechanical effects, a numerical model of poroelastic rock materials was developed using COMSOL, a commercialized multiphysics finite element software package, and compared with the analytical model developed by Wang (2000). Secondly, a series of sensitivity analyses was conducted to correlate the effect of poroelastic parameters on the behavior of porous material. The results of the sensitivity analysis show that porosity and Biot's coefficient has dominant contribution to porous material behavior. Thirdly, a coupled hydromechanical finite element model was developed for a real-world example of embankment consolidation. The simulation results show excellent agreement to field measurements of embankment settlement data.
M.S.
Masters
Civil, Environmental, and Construction Engineering
Engineering and Computer Science
Civil Engineering; Structures and Geotechnical Engineering
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Linden, d’Hooghvorst Rodríguez Jean Joseph van der. "Geomechanical study of the Tarfaya basin, West African coast, using 3D/2D static models and 2D evolutionary models." Doctoral thesis, Universitat de Barcelona, 2021. http://hdl.handle.net/10803/672449.

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This thesis uses different variants of geomechanical modelling approaches to investigate stress, strain and geometry distribution and evolution through time of the Tarfaya salt basin, located on the West African coast. This work has been conducted by geomechanically simulating a sector of the Tarfaya basin containing key features such as diapirs, faults and encasing sediments using 3D and 2D static models and 2D evolutionary models. The 3D and 2D static geomechanical models of the Tarfaya basin system allowed to predict the stresses and strains at present day. Both models are based on present-day basin geometries extracted from seismic data and use a poro-elastic description for the sediments based on calibrated log data and a visco-plastic description for the salt based on values from Avery Island. The models predict a significant horizontal stress reduction in the sediments located at the top of the principal salt structure, the Sandia diapir, consistent with wellbore data. However, the 2D static geomechanical model shows broader areas affected by the stress reduction compared to the 3D model and overestimates its magnitude by less than 1.5 MPa. These results highlight the possibility of using 2D static modelling as a valid approximation to the more complex and time-consuming 3D static models. A more in-depth study of the 2D static model using sensitivity analysis yielded a series of interesting observations: (1) the salt bodies and their geometry have the strongest impact on the final model results; (2) the elastic properties of the sediments do not impact the model results. In other words, the correct definition of the sediments with the highest material contrasts such as salt should be a priority when building static models. Such definition should be ranked ahead of the precise determination of the rheologic parameters for the sediments present in the basin. In this thesis, we also present the results of introducing an evolutionary geomechanical modelling approach to the Tarfaya basin. This study incorporates information of burial history, sea floor geometry and tectonic loads from a sequential kinematic restoration model to geologically constrain the 2D evolutionary geomechanical model. The sediments in the model follow a poro-elastoplastic description and the salt follows a visco-plastic description. The 2D evolutionary model predicts a similar Sandia diapir evolution when compared to the kinematic restoration. This proves this approach can offer a significant advance in the study of the basin, by not only providing the stress and strain distribution and salt geometry at present day, but also reproducing their evolution during the Tarfaya basin history. Sensitivity analysis on the evolutionary model indicates that temporal and spatial variation in sedimentation rate is a key control on the kinematic structural evolution of the salt system. The variation of sedimentation rates in the model controls whether the modelled salt body gets buried by Tertiary sediments (after a continuous growth during the Jurassic and Cretaceous periods) or is able to remain active until the present day. Also, the imposed shortening affects the final stress distribution of the sediments at the present day. To conclude, the results obtained during this study allowed us to understand the formation and evolution of the diapirs in the Tarfaya basin using carefully built geomechanical models. The study demonstrates that carefully built 2D static models can provide information comparable to the 3D models, but without the time and computational power requirements of the 3D models. That makes the 2D approach very appropriate for the exploration stages of a particular prospect. If carefully built, such 2D models can approximate and yield useful information, even from complex 3D structures such as the Tarfaya basin salt structures. This thesis also concludes that incorporating kinematic restoration data into 2D evolutionary models provides insights into the key parameters controlling the evolution of the studied system. Furthermore, it enables more realistic geomechanical models, which, in turn, provide more insights into sediment stress and porosity.
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Maury, Julie. "Analyse du potentiel sismique d'un secteur lithosphérique au nord ouest des Alpes." Phd thesis, Université de Strasbourg, 2013. http://tel.archives-ouvertes.fr/tel-00873526.

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Le nord-ouest des Alpes est un domaine intraplaque présentant de très faibles déformations. C'est pourquoi il paraît délicat de déduire la probabilité d'occurrence d'un séisme de taille lithosphérique (magnitude supérieure à 7) à partir des observations de microsismicité. De telles observations sont en effet des processus superficiels et présentent peu ou pas de lien avec des processus profonds de plus grande ampleur. L'objectif est de déterminer le potentiel sismique d'un secteur au nord-ouest des Alpes en étudiant le champ de contrainte résultant d'un chargement gravitaire. Seuls les objets de taille lithosphérique, i.e. de l'ordre de la centaine de kilomètres sont pris en compte. Un modèle de contraintes à l'échelle 360 km par 400 km par 230 km d'épaisseur, centré sur la subduction fossile des Alpes de l'ouest et s'étendant jusqu'au nord de Strasbourg, est établi. L'étude des structures du nord-ouest alpin montre l'importance de l'orogène alpin qui se retrouve, enparticulier, dans les variations de profondeur des interfaces de la lithosphère. Une étude du champ de contrainte dans le socle a permis d'identifier une rotation des contraintes principales horizontales avec l'axe des Alpes. Bien que la valeur absolue des contraintes principales n'ait pas pu être déterminée, un rapport de valeur relative est calculé. Le résultat de la modélisation montre l'importance de la rhéologie dans le cas d'un chargement gravitaire. Si une rhéologie élastique est prise en compte, les directions de contrainte calculées sont totalement différentes des observations. Par contre, l'utilisation d'une rhéologie élasto-plastique combinée à l'utilisation d'une géométrie réaliste des interfaces lithosphériques permet d'obtenir des directions de contraintes cohérentes avec les données.
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Books on the topic "Geomechanical model"

1

International Symposium on Numerical Models in Geomechanics (3rd 1989 Niagara Falls, Ont.). Numerical models in geomechanics. London: Elsevier Applied Science, 1989.

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International Symposium on Numerical Models in Geomechanics (4th 1992 Swansea, Wales). Numerical models in geomechanics: Proceedings of the fourth international symposium on numerical models in geomechanics. Rotterdam: A.A. Balkema, 1992.

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Sharma, V. M. Distinct element modelling in geomechanics. Edited by Saxena K. R and Woods Richard D. Rotterdam: A.A. Balkema, 1999.

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International Symposium on Numerical Models in Geomechanics. (2nd 1986 Ghent, Belgium). Numerical models in geomechanics: Proceedings of the International Symposium on Numerical Models in Geomechanics, Ghent, 31st March-4th April, 1986. Redruth, England: Jackson, 1986.

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Multiscale geomechanics: From soil to engineering projects. London: ISTE, Ltd. ; Hoboken, NJ : John Wiley & Sons, 2011.

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Cavity expansion methods in geomechanics. Dordrecht: Kluwer Academic Publishers, 2000.

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International Symposium on Numerical Models in Geomechanics. (10th 2007 Rhodes, Greece). Numerical models in geomechanics: Proceedings of the 10th International Symposium on Numerical Models in Geomechanics (NUMOG X), Rhodes, Greece, 25-27 April 2007. Edited by Pande G. N and Pietruszczak S. London: Taylor & Francis, 2007.

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International Symposium on Numerical Models in Geomechanics (5th 1995 Davos, Switzerland). Numerical models in geomechanics: Proceedings of the fifth International Symposium on Numerical Models in Geomechanics : NUMOG V, Davos, Switzerland, 6-8 September 1995. Rotterdam: A.A. Balkema, 1995.

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Alonso, Eduardo E. Geomechanics of Failures. Advanced Topics. Dordrecht: Springer Science+Business Media B.V., 2010.

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International Symposium on Numerical Models in Geomechanics (6th 1997 Montréal, Québec). Numerical models in geomechanics: NUMOG VI : proceedings of the Sixth International Symposium on Numerical Models in Geomechanics, Montreal, Quebec, Canada, 2-4 July, 1997. Rotterdam: A.A. Balkema, 1997.

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Book chapters on the topic "Geomechanical model"

1

Savenkov, E. B., and V. E. Borisov. "Geomechanical Model for Large Scale Hydraulic Fracture Dynamics." In Heat-Mass Transfer and Geodynamics of the Lithosphere, 259–71. Cham: Springer International Publishing, 2021. http://dx.doi.org/10.1007/978-3-030-63571-8_16.

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Lade, Poul V. "Three-dimensional behaviour and parameter evaluation of an elastoplastic soil model." In Geomechanical Modelling in Engineering Practice, 297–311. London: Routledge, 2021. http://dx.doi.org/10.1201/9780203753583-15.

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Khadka, Suraj, Zhong-Mei Wang, and Liang-Bo Hu. "Exploring a Coupled Approach to Model the Geomechanical Processes of Sinkholes." In Proceedings of GeoShanghai 2018 International Conference: Geoenvironment and Geohazard, 99–107. Singapore: Springer Singapore, 2018. http://dx.doi.org/10.1007/978-981-13-0128-5_12.

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Xiangning, Xu, Chen Yuliang, and Li Shengwen. "Study of Shock Landslide-Type Geomechanical Model Test for Consequent Rock Slope." In Landslide Science and Practice, 11–16. Berlin, Heidelberg: Springer Berlin Heidelberg, 2013. http://dx.doi.org/10.1007/978-3-642-31310-3_2.

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Perello, P. "The Geological Model Reliability in Tunnelling and Its Influence on the Geomechanical Model: A Quantification Attempt." In Challenges and Innovations in Geomechanics, 976–84. Cham: Springer International Publishing, 2021. http://dx.doi.org/10.1007/978-3-030-64514-4_107.

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Kamenev, Pavel, Leonid Bogomolov, and Andrey Zabolotin. "Development of Geomechanical Model of the South Segment of Central Sakhalin Fault Zone." In Springer Proceedings in Earth and Environmental Sciences, 79–86. Cham: Springer International Publishing, 2019. http://dx.doi.org/10.1007/978-3-030-31970-0_9.

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Pereira, Jose Henrique, and Nicole Borchardt. "UHE Belo Monte: Geological and Geomechanical Model of Intake Foundation of Belo Monte Site." In Engineering Geology for Society and Territory - Volume 6, 627–32. Cham: Springer International Publishing, 2014. http://dx.doi.org/10.1007/978-3-319-09060-3_111.

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Xu, Zhijie, Yilin Fang, Timothy D. Scheibe, and Alain Bonneville. "A Hydro-Mechanical Model and Analytical Solutions for Geomechanical Modeling of Carbon Dioxide Geological Sequestration." In Energy Technology 2012, 47–53. Hoboken, NJ, USA: John Wiley & Sons, Inc., 2012. http://dx.doi.org/10.1002/9781118365038.ch7.

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Stockinger, Georg, Elena Mraz, Florian Menschik, and Kurosch Thuro. "Geomechanical Model for a Higher Certainty in Finding Fluid Bearing Regions in Non-porous Carbonate Reservoirs." In IAEG/AEG Annual Meeting Proceedings, San Francisco, California, 2018—Volume 6, 193–98. Cham: Springer International Publishing, 2018. http://dx.doi.org/10.1007/978-3-319-93142-5_27.

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Nguyen, Van Hung, Hai Linh Luong, Minh Hoang Truong, Huu Truong Nguyen, Vu The Quang, Viet Khoi Nguyen Nguyen, and Tu An Bui. "Application of a Geomechanical Model to Wellbore Stability Analysis: A Case Study X-Well, Bach Ho Field in Vietnam." In Lecture Notes in Civil Engineering, 177–82. Singapore: Springer Singapore, 2018. http://dx.doi.org/10.1007/978-981-13-2306-5_23.

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Conference papers on the topic "Geomechanical model"

1

Rodriguez-Herrera, A., O. Zdraveva, and N. Koutsabeloulis. "Geomechanical Velocity Model Building." In 76th EAGE Conference and Exhibition 2014. Netherlands: EAGE Publications BV, 2014. http://dx.doi.org/10.3997/2214-4609.20141073.

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Bérard, T., J. Desroches, Y. Yang, X. Weng, and K. Olson. "High-Resolution 3D Structural Geomechanics Modeling for Hydraulic Fracturing." In SPE Hydraulic Fracturing Technology Conference. SPE, 2015. http://dx.doi.org/10.2118/spe-173362-ms.

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Abstract Three-dimensional (3D) geomechanical models built at reservoir scale lack resolution at the well sector scale (e.g., hydraulic fracture scale), at least laterally. One-dimensional (1D) geomechanical models, on the other hand, have log resolution along the wellbore but no penetration away from it—along the fracture length for instance. Combining borehole structural geology based on image data and finite elements (FE) geomechanics, we constructed and calibrated a 3D, high-resolution geomechanical model, including subseismic faults and natural fractures, over a 1,500- × 5,200- × 300-ft3 sector around a vertical pilot and a 3,700-ft lateral in the Fayetteville shale play. Compared to a 1D approach, we obtained a properly equilibrated stress field in 3D space, in which the effect of the structure, combined with that of material anisotropy and heterogeneity, are accounted for. These effects were observed to be significant on the stress field, both laterally and local to the faults and natural fractures. The model was used to derive and map in 3D space a series of geomechanically based attributes potentially indicative of hydraulic fracturing performance and risks, including stress barriers, fracture geometry attributes, near-well tortuosity, and the level of stress anisotropy. An interesting match was observed between some of the derived attributes and fracturing data—near-wellbore pressure drop and overall ease and difficulty to place a treatment—encouraging their use for perforation and stage placement or placement of the next nearby lateral. The model was also used to simulate hydraulic fracturing, taking advantage of such a 3D structural and geomechanical representation. It was shown that the structure and heterogeneity captured by the model had a significant impact on hydraulic fracture final geometry.
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Li, Pingke, and Richard J. Chalaturnyk. "Geomechanical Model of Oil Sands." In SPE International Thermal Operations and Heavy Oil Symposium. Society of Petroleum Engineers, 2005. http://dx.doi.org/10.2118/97949-ms.

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Santos, Luiz Alberto, Anderson Moraes, Aline Theophilo da Silva, Vinicius Ferreira Carneiro, Paulo Marcos de Carvalho, Mauren Paola Ruthner, and Henrique Aita Fraquelli. "Seismically guided exploration geomechanical model." In 15th International Congress of the Brazilian Geophysical Society & EXPOGEF, Rio de Janeiro, Brazil, 31 July-3 August 2017. Brazilian Geophysical Society, 2017. http://dx.doi.org/10.1190/sbgf2017-064.

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Purnomo, Eko Widi, and Deva Prasad Ghosh. "Geomechanical Model from Subseismic Resolution Data." In Offshore Technology Conference Asia. Offshore Technology Conference, 2016. http://dx.doi.org/10.4043/26642-ms.

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Lopez-Puiggene, Eva, Nubia Aurora Gonzalez-Molano, Jose Alvarellos-Iglesias, Jose M. Segura, and M. R. Lakshmikantha. "Numerical Modeling of Sand Production Potential Estimation and Passive Control Optimization: A Case Study." In ASME 2018 37th International Conference on Ocean, Offshore and Arctic Engineering. American Society of Mechanical Engineers, 2018. http://dx.doi.org/10.1115/omae2018-77851.

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Solids/sand production is an unintended byproduct of the hydrocarbon production that, from an operational point of view, might potentially lead to undesirable consequences. This paper focuses on a study centered in the geomechanical perspective for solids production. An integrated workflow is presented to analyze the combined effect of reservoir pore-pressure, drawdown, in-situ stress, rock properties and well/perforations orientation on the onset of solid production. This workflow incorporates analyses at multiple scales: rock constitutive modeling at lab scale, 1D geomechanical models at wellbore scale along well trajectories, a 3D geomechanical model at the reservoir scale and 3D/4D high resolution reservoir - geomechanical coupled models at the well and perforation scale. 1D geomechanical models were built using log and field data, drilling experience and laboratory tests in order to characterize in situ stresses, pore pressure and rock mechanics properties (stiffness and strength) profiles for several wells. Rock shear failure mechanism was also analyzed in order to build a pre-drill model and evaluate the wellbore stability from a geomechanical point of view. Pre-production stress modeling was simulated to obtain a representative initial stress state integrating 1D geomechanics well results, 3D dynamic model and seismic interpretations. Mechanical properties were distributed considering properties calculated in the 1D geomechanical models as input. 3D stress field was validated with in-situ stress profiles from 1D modeling results. This simulated pre-production stress state was then used as an initial condition for the reservoir - geomechanical coupled simulations. Effective stress changes and deformations associated to pore pressure changes were calculated including the coupling between reservoir and geomechanical modeling. Finally, a 3D/4D high resolution well scale reservoir - geomechanical coupled numerical model was built in order to determine the threshold of sand production. A limit of plastic strain was obtained based on numerical simulations of available production data, DST and ATWC tests. This critical plastic strain limit was used as a criterion (strain-based) for rock failure to define the onset of sand production as a function of pore pressure, perforation orientation and rock strength. Conclusions regarding the perforation orientations related to the possibility of producing solids can support operational decisions in order to avoid undesirable solid production and therefore optimize the production facilities capacity and design to handle large amounts of solids and/or the clogging of the well.
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Bhimpalli, Sarah, Ashok Shinde, Bayye L. Rao, Satya Perumalla, Anjana Panchakarla, Prajit Chakrabarti, and Sankhajit Saha. "Successful Implementation Of Geomechanics In Deep Water Setting: A Case Study From KG Offshore, India." In SPE/IADC Middle East Drilling Technology Conference and Exhibition. SPE, 2021. http://dx.doi.org/10.2118/202146-ms.

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Abstract Geomechanics has an important role in assessing formation integrity during well construction and completion. It also has its effect when the wellbore is in production mode. Geomechanical study evaluate the impact of the present day in-situ stress and related mechanical processes on reservoir management. The study field ‘K' belongs to Plio-Pleistocene sequence of deep-water environment with hydrocarbon prospects. This belongs to Post-Rift tectonic stage of evolution with hydrocarbon occurring in structurally controlled traps. As a part of exploration activity, four offset oil wells were drilled earlier which were considered for the geomechanical model construction. Field (K) development plan comprising of six hydrocarbon producers and four water injectors was prepared. Considering the thick water column (300m-650m) in this deep water area of offshore and young unconsolidated sedimentary sequence in the sub-surface, expected pore-pressures can be high whereas the fracture gradient can be low. As a result, the safe drilling mud window can be narrow. Upon successful drilling of a well in such challenging environment without NPT (Non-Productive time), completing the well with best possible technologies suitable to the reservoir's mechanical behavior is utmost important for maximizing the production and minimizing the risk. To mitigate these problems in developing this field, an integrated reservoir geomechanics approach is adopted to optimize the drilling plan and reservoir completion parameters for the planned well. This paper covers the geomechanical study of four wells namely W, X, Y & Z drilled in the field ‘K'. The principal constituents of the geomechanical model are in-situ stresses, pore pressure and the rock mechanical properties. Geomechanical model for the field ‘K' was built utilizing the available data by integrating drilling, geology, petrophysics and reservoir data. Methodology adopted in this paper also highlights how a reliable geomechanical model can be built for a field, which is having data constraints. Constraining of stress magnitudes, orientation and anisotropy added value for efficient well planning in deep waters reservoirs. Calculating well specific reservoir rock mechanical properties, it made possible to identify the most optimal completion strategy. Approach contributed knowledge of geomechanical parameters based on the data of four offset wells has been used for successfully drilling and completion of all the subsequent wells without major challenges. Overall, geomechanical modeling has played a major role in drillability and deliverability of the reservoir. Integrated approach adopted in this paper can be used for well planning and drilling of future wells in East Coast of India with similar geological set up.
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Venter, Julian, and Emrich Hamman. "A practical safety risk model for monitoring program design." In First International Conference on Mining Geomechanical Risk. Australian Centre for Geomechanics, Perth, 2019. http://dx.doi.org/10.36487/acg_rep/1905_09_venter.

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Andrijasevich, Jake, Hakan Basarir, and Johan Wesseloo. "Construction of a damage risk model for footwall drifts." In First International Conference on Mining Geomechanical Risk. Australian Centre for Geomechanics, Perth, 2019. http://dx.doi.org/10.36487/acg_rep/1905_15_andrijasevich.

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Fanchi, J. R. "Estimating Geomechanical Properties Using an Integrated Flow Model." In SPE/DOE Improved Oil Recovery Symposium. Society of Petroleum Engineers, 2002. http://dx.doi.org/10.2118/75149-ms.

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Reports on the topic "Geomechanical model"

1

Park, Byoung. Geomechanical Simulation of Bayou Choctaw Strategic Petroleum Reserve - Model Calibration. Office of Scientific and Technical Information (OSTI), February 2017. http://dx.doi.org/10.2172/1345900.

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Park, Byoung. Geomechanical Simulation of Big Hill Strategic Petroleum Reserve - Model Calibration. Office of Scientific and Technical Information (OSTI), December 2018. http://dx.doi.org/10.2172/1761931.

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Park, Byoung. Geomechanical Simulation of Big Hill Strategic Petroleum Reserve - Calibration of Model Containing Shear Zone. Office of Scientific and Technical Information (OSTI), September 2019. http://dx.doi.org/10.2172/1569339.

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Um, Wooyong, Hun Bok Jung, Senthil Kabilan, Dong-Myung Suh, and Carlos A. Fernandez. Geochemical and Geomechanical Effects on Wellbore Cement Fractures: Data Information for Wellbore Reduced Order Model. Office of Scientific and Technical Information (OSTI), January 2014. http://dx.doi.org/10.2172/1121533.

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Deo, Milind, Hai Huang, Hyukmin Kweon, and Luanjing Guo. Reactive Transport Models with Geomechanics to Mitigate Risks of CO2 Utilization and Storage. Office of Scientific and Technical Information (OSTI), March 2016. http://dx.doi.org/10.2172/1261781.

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Delshad, Mojdeh, Mary Wheeler, Kamy Sepehrnoori, and Gary Pope. Development of an Advanced Simulator to Model Mobility Control and Geomechanics during CO{sub 2} Floods. Office of Scientific and Technical Information (OSTI), December 2013. http://dx.doi.org/10.2172/1130970.

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