Academic literature on the topic 'Thermal reservoir simulation'
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Journal articles on the topic "Thermal reservoir simulation"
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Zaydullin, Rustem, Denis V. Voskov, Scott C. James, Heath Henley, and Angelo Lucia. "Fully compositional and thermal reservoir simulation." Computers & Chemical Engineering 63 (April 2014): 51–65. http://dx.doi.org/10.1016/j.compchemeng.2013.12.008.
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Winterfeld, P. H., and Yu-Shu Wu. "Simulation of Coupled Thermal/Hydrological/Mechanical Phenomena in Porous Media." SPE Journal 21, no. 03 (June 15, 2016): 1041–49. http://dx.doi.org/10.2118/173210-pa.
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Summary For processes such as production from low-permeability reservoirs and storage in subsurface formations, reservoir flow and the reservoir stress field are coupled and affect one another. This paper presents a thermal/hydrological/mechanical (THM) reservoir simulator that is applicable to modeling such processes. The fluid- and heat-flow portion of our simulator is for general multiphase, multicomponent, multiporosity systems. The geomechanical portion consists of an equation for mean stress, derived from linear elastic theory for a thermo-poroelastic system, and equations for stress-tensor components that depend on mean stress and other variables. The integral finite-difference method is used to solve these equations. The mean-stress and reservoir-flow variables are solved implicitly, and the remaining stress-tensor components are solved explicitly. Our simulator is verified by use of analytical solutions for stress- and strain-tensor components and is compared with published results.
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Swinkels, Wim J. A. M., and Rik J. J. Drenth. "Thermal Reservoir Simulation Model of Production From Naturally Occurring Gas Hydrate Accumulations." SPE Reservoir Evaluation & Engineering 3, no. 06 (December 1, 2000): 559–66. http://dx.doi.org/10.2118/68213-pa.
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Summary Reservoir behavior of a hydrate-capped gas reservoir is modeled using a three-dimensional thermal reservoir simulator. The model incorporates a description of the phase behavior of the hydrates, heat flow and compaction in the reservoir and the hydrate cap. The model allows the calculation of well productivity, evaluation of well configurations and matching of experimental data. It shows the potentially self-sealing nature of the hydrate cap. Production scenarios were also investigated for production from the solid hydrate cap using horizontal wells and various ways of dissociating the gas hydrates. These investigations show the role of excessive water production and the requirement for water handling facilities. A data acquisition program is needed to obtain reservoir parameters for gas hydrate accumulations. Such parameters include relative phase permeability, heat capacity and thermal conductivity of the hydrate-filled formations, compaction parameters and rate of hydrate formation and decomposition in the reservoir. Introduction Interest in natural gas hydrates is increasing with foreseen requirements in the next century for large volumes of natural gas as a relatively clean hydrocarbon fuel and with increasing exploration and production operation experience in deepwater and Arctic drilling. While progress is being made in identifying and drilling natural gas hydrates, there is also the need to look ahead and develop production concepts for the potentially large deposits of natural gas hydrates and hydrate-capped gas reservoirs. We are now reaching the stage in which some of the simplifying assumptions of analytical models are not sufficient any longer for developing production concepts for natural gas hydrate accumulations. For this reason we have investigated the option of applying a conventional industrial thermal reservoir simulator to model production from natural gas hydrates. Reservoir behavior of free gas trapped under a hydrate seal is to a great extent similar to the behavior of a conventional gas field with the following major differences:thermal effects on the overlying hydrate cap have to be taken into account;potentially large water saturations can build up in the reservoir;relatively low pressures;high formation compressibility can be expected. Use of a thermal compositional reservoir simulator to model the behavior of hydrates and hydrate-capped gas has not been attempted before. We have shown before1 that existing knowledge of phase behavior and thermal reservoir modeling can be fruitfully combined to better understand the behavior of natural gas hydrates in the subsurface. In this paper we will expand on this work and provide further results. After an overview of the model setup, we will first show some results for modeling the depletion of the gas accumulations underlying the hydrate layer. This will be followed by the results for production from the hydrate layer itself, applying heat injection in the formation. Modeling Natural Hydrate Associated Production Attempts to model the behavior of hydrate-capped gas and hydrate reservoirs have been documented by various authors in the literature. Simple energy balance approaches are used by Kuuskraa and Hammershaimb et al.2 Masuda et al.,3 Yousif et al.,4 and Xu and Ruppel5 have presented numerical solutions to analytical models. The first two of these papers do not include thermal effects in their calculations. Reference 5 is specifically aimed at the formation phase of hydrates in the reservoir over geological times, and is less relevant to the production phase. An attempt at explaining the production behavior of a possibly hydrate-capped gas accumulation is described by Collett and Ginsburg.6 The depth and thickness of the hydrate layer under various conditions were described by Holder et al.7 and by Hyndman et al.8 All these approaches apply analytical methods to explain the subsurface occurrence and behavior of natural gas hydrates using various simplifying assumptions. In earlier work1 we have shown that modeling the reservoir behavior of hydrate-capped gas reservoirs with a three-dimensional (3D) thermal hydrocarbon reservoir simulator allows us to account for reservoir aspects, which are disregarded in most analytical models. Such aspects includewell inflow pressure drop and the effects of horizontal and vertical wells in the reservoir;heat transfer between the reservoir fluids and the formation;the geothermal gradient;phase behavior and pressure/volume/temperature (PVT) properties of the reservoir fluids as a fluction of pressure decline;internal architecture and geometry of the reservoir; andreservoir compaction effects. Objective The current study was undertaken to show the feasibility of modeling production behavior of a hydrate-capped gas reservoir in a conventional 3D thermal reservoir simulation model. Objectives of the modeling work include the following.Understand reservoir behavior of natural gas hydrates and hydrate-capped reservoirs. Important aspects of the reservoir thermodynamics are the potential self-preservation capacity of the hydrate cap, the limitation on hydrate decomposition imposed by the thermal conductivity of the rock and the influence of compaction.Confirm material and energy balance analytical calculations.Investigate production options, such as the application of horizontal wells.Calculate well productivity and evaluate well configurations. This study was performed as part of an ongoing project involving other geological and petroleum engineering disciplines. Accounting for Thermal Effects In this study the thermal version of an in-house hydrocarbon reservoir simulator is used.9 We represent the reservoir fluids by a gaseous, a hydrate and an aqueous phase, which are made up of three components, two hydrocarbons and a water component.
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Liu, Hui, Zhangxin Chen, Lihua Shen, Xiaohu Guo, and Dongqi Ji. "Well modelling methods in thermal reservoir simulation." Oil & Gas Science and Technology – Revue d’IFP Energies nouvelles 75 (2020): 63. http://dx.doi.org/10.2516/ogst/2020058.
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Reservoir simulation is of interdisciplinary research, including petroleum engineering, mathematics, and computer sciences. It studies multi-phase (water, oil and gas) flow in porous media and well modelling. The latter describes well behavior using physical and mathematical methods. In real world applications, there are many types of wells, such as injection wells, production wells and heaters, and their various operations, such as pressure control, rate control and energy control. This paper presents commonly used well types, well operations, and their mathematical models, such as bottom hole pressure, water rate, oil rate, liquid rate, subcool, and steam control. These are the most widely applied models in thermal reservoir simulations, and some of them can even be applied to the black oil and compositional models. The purpose of this paper is to review these well modelling methods and their mathematical models, which explain how the well operations are defined and computed. We believe a detailed introduction is important to other reseachers and simulator developers. They have been implemented in our in-house parallel thermal simulator. Numerical experiments have been carried out to validate the model implementations and demonstrate the scalability of the parallel thermal simulator.
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Ayache, Simon V., Violaine Lamoureux-Var, Pauline Michel, and Christophe Preux. "Reservoir Simulation of Hydrogen Sulfide Production During a Steam-Assisted-Gravity-Drainage Process by Use of a New Sulfur-Based Compositional Kinetic Model." SPE Journal 22, no. 01 (August 3, 2016): 080–93. http://dx.doi.org/10.2118/174441-pa.
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Summary Steam injection is commonly used as a thermal enhanced-oil-recovery (EOR) method because of its efficiency for recovering hydrocarbons, especially from heavy-oil and bitumen reservoirs. Reservoir models simulating this process describe the thermal effect of the steam injection, but generally neglect the chemical reactions induced by the steam injection and occurring in the reservoir. In particular, these reactions can lead to the generation and production of the highly toxic and corrosive acid gas hydrogen sulfide (H2S). The overall objective of this paper is to quantitatively describe the chemical aquathermolysis reactions that occur in oil-sands reservoirs undergoing steam injections and to provide oil companies with a numerical model for reservoir simulators to forecast the H2S-production risks. For that purpose, a new sulfur-based compositional kinetic model has been developed to reproduce the aquathermolysis reactions in the context of reservoir modeling. It is derived from results gathered on an Athabasca oil sand from previous laboratory aquathermolysis experiments. In particular, the proposed reactions model accounts for the formation of H2S issued from sulfur-rich heavy oils or bitumen, and predicts the modification of the resulting oil saturate, aromatic, resin, and asphaltene (SARA) composition vs. time. One strength of this model is that it is easily calibrated against laboratory-scale experiments conducted on an oil-sand sample. Another strength is that its calibration is performed while respecting the constraints imposed by the experimental data and the theoretical principles. In addition, in this study no calibration was needed at reservoir scale against field-production data. In the paper, the model is first validated with laboratory-scale simulations. The thermokinetic modeling is then coupled with a 2D reservoir simulation of a generic steam-assisted gravity drainage (SAGD) process applied on a generic Athabasca oil-sand reservoir. This formulation allows investigating the H2S generation at reservoir scale and quantifying its production. The H2S- to bitumen-production ratio against time computed by the reservoir simulation is found to be consistent with production data from SAGD operations in Athabasca, endorsing the proposed methodology.
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Yashin, A., I. Indrupskiy, and O. Lobanova. "Simulation of composition changes in reservoirs with large hydrocarbon columns and temperature gradient." Georesursy 20, no. 4 (November 30, 2018): 336–43. http://dx.doi.org/10.18599/grs.2018.4.336-343.
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This paper compares three methods for calculation of initial composition variation with depth in hydrocarbon reservoirs: considering thermal diffusion, considering temperature gradient without thermal diffusion effects; and by gravity forces only. Newton method-based numerical algorithm was implemented for solution of thermodynamic equations to evaluate pressure and hydrocarbon composition. Test calculations are performed for main gas-condensate reservoir of Vuktylskoye field with a gas column of 1350 m. The results obtained with the numerical algorithm indicate that gravity segregation impact is the strongest for all the cases considered. Concentration decreases with depth for low molecular weight components and increases for high molecular weight components. The higher molecular weight of the component, the stronger variation of its concentration with depth. Initial reservoir pressure also changes accordingly. However, thermal diffusion also has a significant influence on variation of hydrocarbon composition with depth and initial reservoir pressure. For the test case considered, thermal diffusion magnifies the impact of gravity and results in strongly nonlinear dependencies of component concentrations on depth. When thermal gradient is taken into account without thermal diffusion effects, the results are only slightly different from those with the isothermal gravity segregation calculations. None of the calculation methods were successful in matching estimates of initial composition variation with depth obtained from well exploitation data. Physical mechanisms governing variation of composition within the main reservoir of the Vuktylskoye field require additional investigation. Despite the long history of the reservoir development, this problem was previously studied based only on field development data.
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Jansen, Gunnar, and Stephen A. Miller. "On the Role of Thermal Stresses during Hydraulic Stimulation of Geothermal Reservoirs." Geofluids 2017 (2017): 1–15. http://dx.doi.org/10.1155/2017/4653278.
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Massive quantities of fluid are injected into the subsurface during the creation of an engineered geothermal system (EGS) to induce shear fracture for enhanced reservoir permeability. In this numerical thermoelasticity study, we analyze the effect of cold fluid injection on the reservoir and the resulting thermal stress change on potential shear failure in the reservoir. We developed an efficient methodology for the coupled simulation of fluid flow, heat transport, and thermoelastic stress changes in a fractured reservoir. We performed a series of numerical experiments to investigate the effects of fracture and matrix permeability and fracture orientation on thermal stress changes and failure potential. Finally, we analyzed thermal stress propagation in a hypothetical reservoir for the spatial and temporal evolution of possible thermohydraulic induced shear failure. We observe a strong influence of the hydraulic reservoir properties on thermal stress propagation. Further, we find that thermal stress change can lead to induced shear failure on nonoptimally oriented fractures. Our results suggest that thermal stress changes should be taken into account in all models for long-term fluid injections in fractured reservoirs.
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Yu, Xinan, Xiaoping Li, Shuoliang Wang, and Yi Luo. "A Multicomponent Thermal Fluid Numerical Simulation Method considering Formation Damage." Geofluids 2021 (January 14, 2021): 1–15. http://dx.doi.org/10.1155/2021/8845896.
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Multicomponent thermal fluid huff and puff is an innovative heavy oil development technology for heavy oil reservoirs, which has been widely used in offshore oilfields in China and has proved to be a promising method for enhancing oil recovery. Components of multicomponent thermal fluids contain many components, including carbon dioxide, nitrogen, and steam. Under high temperature and high pressure conditions, the complex physical and chemical reactions between multicomponent thermal fluids and reservoir rocks occur, which damage the pore structure and permeability of core. In this paper, the authors set up a reservoir damage experimental device, tested the formation permeability before and after the injection of multiple-component thermal fluids, and obtained the formation damage model. The multicomponent thermal fluid formation damage model is embedded in the component control equation, the finite difference method is used to discretize the control equation, and a new multielement thermal fluid numerical simulator is established. The physical simulation experiment of multicomponent thermal fluid huff and puff is carried out by using the actual sand-packed model. By comparing the experimental results with the numerical simulation results, it is proved that the new numerical simulation model considering formation damage proposed in this paper is accurate and reliable.
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Sabeti, R., S. Jamali, and H. H. Jamali. "Simulation of Thermal Stratification and Salinity Using the Ce-Qual-W2 Model (Case Study: Mamloo Dam)." Engineering, Technology & Applied Science Research 7, no. 3 (June 12, 2017): 1664–69. http://dx.doi.org/10.48084/etasr.1062.
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Due to the shortage of fresh water, the quality of stored water in reservoirs has become increasingly important. Thermal regime and salinity are factors that affect the quality of water reservoirs. These two parameters were studied in Mamloo Dam in Tehran province. This dam has recently started to be uses as a source of drinking water for Tehran and thus its water quality is of increased importance. In this regard, the hydrodynamic model for 2014 to 2015 was built and calibrated by the CE-QUAL-W2 model and the model was used to simulate the thermal regime and salinity up to 2020. Two main scenarios were studied in this period, the continuation of the current situation or a 2.5% increase in water requirements and 5% decrease in discharge. The results show that the reservoir will experience thermal stratification in the summer and vertical mixing in the winter. Dased on these results Mamloo reservoir is in branch of warm Monomictic lake. Also results showed that thermal stratification and ssalinity stratification dominates simultaneity. Besides this issue with 2.5% increase in water requirements and 5% decrease in discharge, duration of summer thermal stratification will decrease although intensity of thermal stratification will increase.
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Dong, Xiao Hu, Hui Qing Liu, Zhan Xi Pang, and Yong Gang Yi. "Variation Characteristics of Reservoir Physical Properties after Thermal Recovery in Heavy Oil Reservoirs." Advanced Materials Research 550-553 (July 2012): 2848–52. http://dx.doi.org/10.4028/www.scientific.net/amr.550-553.2848.
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With the development of heavy oil reservoirs, it faced a series of problems. Using the theory of thermal-hydrological-mechanical (THM) coupling, a predictive model of reservoir physical properties (RPP) after thermal recovery is established. Based on this model, the changing process of reservoir physical properties is simulated by the method of numerical simulation. The obtained results show that the sand production has a significant influence on RPP. By contrast with rock deformation, it has a smaller influence on RPP. The influence caused by the former is about 5~8 times than latter. During the period of steam injection, resulting from the movement of sand grain and expansion of reservoir, both porosity and permeability of reservoir are on the rise. Due to the sand production and reservoir compression, a reducing tendency is happened in the production period. The changes of RPP in reservoir are huge along the main streamline direction, and it might change because of the presence of high-permeability path.
Dissertations / Theses on the topic "Thermal reservoir simulation"
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Agarwal, Anshul. "Thermal adaptive implicit reservoir simulation /." May be available electronically:, 2009. http://proquest.umi.com/login?COPT=REJTPTU1MTUmSU5UPTAmVkVSPTI=&clientId=12498.
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Samadov, Hidayat. "Analyzing Reservoir Thermal Behavior By Using Thermal Simulation Model (sector Model In Stars)." Master's thesis, METU, 2011. http://etd.lib.metu.edu.tr/upload/12613336/index.pdf.
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It is observed that the flowing bottom-hole temperature (FBHT) changes as a result of production, injection or shutting the well down. Variations in temperature mainly occur due to geothermal gradient, injected fluid temperature, frictional heating and the Joule-Thomson effect. The latter is the change of temperature because of expansion or compression of a fluid in a flow process involving no heat transfer or work. CMG STARS thermal simulation sector model developed in this study was used to analyze FBHT changes and understand the reasons. Twenty three main and five additional cases that were developed by using this model were simulated and relation of BHT with other parameters was investigated. Indeed the response of temperature to the change of some parameters such as bottom-hole pressure and gas-oil ratio was detected and correlation was tried to set between these elements. Observations showed that generally FBHT increases when GOR decreases and/or flowing bottom-hole pressure (FBHP) increases. This information allows estimating daily gas-oil ratios from continuously measured BHT. Results of simulation were compared with a real case and almost the same responses were seen. The increase in temperature after the start of water and gas injection or due to stopping of neighboring production wells indicated interwell communications. Additional cases were run to determine whether there are BHT changes when initial temperature was kept constant throughout the reservoir. Different iteration numbers and refined grids were used during these runs to analyze iteration errorshowever no significant changes were observed due to iteration number differences and refined grids. These latter cases showed clearly that variations of temperature don&rsquo
t occur only due to geothermal gradient, but also pressure and saturation changes. On the whole, BHT can be used to get data ranging from daily gas-oil ratios to interwell connection if analyzed correctly.
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Wang, Zhongxiao. "Parallel computation for reservoir thermal simulation An overlapping domain decomposition approach /." Ann Arbor, Mich. : Proquest, 2005. http://proquest.umi.com/pqdweb?index=0&did=954046251&SrchMode=1&sid=1&Fmt=2&VInst=PROD&VType=PQD&RQT=309&VName=PQD&TS=1187901937&clientId=57025.
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PERDOMO, PAUL RICHARD RAMIREZ. "4D SEISMIC, GEOMECHANICS AND RESERVOIR SIMULATION INTEGRATED STUDY APPLIED TO SAGD THERMAL RECOVERY." PONTIFÍCIA UNIVERSIDADE CATÓLICA DO RIO DE JANEIRO, 2009. http://www.maxwell.vrac.puc-rio.br/Busca_etds.php?strSecao=resultado&nrSeq=31856@1.
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PONTIFÍCIA UNIVERSIDADE CATÓLICA DO RIO DE JANEIROAGÊNCIA NACIONAL DE PETRÓLEO
As reservas de óleos pesados têm obtido grande importância devido à diminuição das reservas de óleos leves e ao aumento dos preços do petróleo. Porém, precisa-se de aumentar a viscosidades destes óleos pesados para que possam fluir até superfície. Para reduzir a viscosidade foi escolhida a técnica de recuperação térmica SAGD (Steam Assisted Gravity Drainage) pelos seus altos valores de recobro. A redução da viscosidade é atingida pela transmissão de calor ao óleo pela injeção de vapor, porém uma parte deste calor é transmitida à rocha. Esta transmissão de calor junto com a produção de óleo geram uma variação no estado de tensões no reservatório o que por sua vez geram fenômenos geomecânicos. Os simuladores convencionais avaliam de uma forma muito simplificada estes fenômenos geomecânicos, o que faz necessários uma abordagem mais apropriada que acople o escoamento dos hidrocarbonetos e a transmissão de calor com a deformação da rocha. As mudanças no reservatório, especialmente a variação da saturação, afetam as propriedades sísmicas da rocha, as quais podem ser monitoradas para acompanhar o avanço da frente de vapor. A simulação fluxo-térmica-composicional-geomecânica é integrada à sísmica de monitoramento 4D da injeção de vapor (a través da física de rochas). Existe uma grande base de dados, integrada por propriedades dos fluidos do reservatório (PVT) (usado no arquivo de entrada de simulação de fluxo) e uma campanha de mecânica das rochas. Foram simulados vários cenários geomecânicos considerando a plasticidade e variação da permeabilidade. Foram avaliadas várias repostas geomecânicas e de propriedades de fluidos no pico de pressão e final do processo SAGD. A resposta geomecânica pode ser observada, porém foi minimizada devido à baixa pressão de injeção, sendo o mecanismo de transmissão de calor um fator importante na produção de óleo (pela redução da viscosidade) e a separação vertical entre poços. Foi também significativa à contribuição da plasticidade no aumento da produção de hidrocarbonetos. A impedância acústica foi calculada usando a Equação de substituição de fluidos de Gassmann. Os sismogramas sintéticos de incidência normal (para monitorar o avanço da frente o câmara de vapor) mostraram a área afetada pela injeção de vapor, porém com pouca variação devida principalmente à rigidez da rocha.
The heavy oil reserves have gained importance due to the decreasing of the present light oil reserves. Although it is necessary to reduce the oil viscosity and makes it flows to surface. For its high recovery factor the SAGD (Steam Assited Gravity Drainage) thermal process was selected. The viscosity reduction is achieved by heat transfer from steam to oil, but some part of this heat goes to rock frame. This heat transfer together with oil production change the initial in-situ stress field what creates geomechanical effects. The conventional flux simulators have a very simplified approach of geomechanical effects, so it is necessary to consider a more suitable approach that considers the coupling between oil flux and heat transfer with rock deformation. The changes within the reservoir, specially the saturation change, affect the seismical rock properties which can be used to monitor the steam chamber growth. The flux-thermal geomechanics is integrated to steam chamber monitoring 4D seismic (through the rock physics). There is a great data base, integrated by reservoir fluid properties (PVT) (used in reservoir simulation dataset) and a rock mechanics campaign. Several scenaries were simulated considering the plasticity and permeability variation. Several geomechanical responses and flux properties at peak pressure and end of SAGD process were evaluated. The geomechanical response can be observed, but was minimized due to low steam injection pressure, being the heat transfer an important in oil production (for the viscosity reduction) and the vertical well separation, too. The plasticity has a significant contribution in the increment of oil production. Acoustic impedance was calculated by using Gassmann fluid substitution approach. 2D Synthetic seismograms, normal incidence (to monitor the steam camera front advance), showed the area affected by steam injection, but with little variation due principally to rock stiffness.
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Mago, Alonso Luis. "Adequate description of heavy oil viscosities and a method to assess optimal steam cyclic periods for thermal reservoir simulation." Thesis, Texas A&M University, 2003. http://hdl.handle.net/1969.1/3951.
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A global steady increase of energy consumption coupled with the decline of conventional oil resources points to a more aggressive exploitation of heavy oil. Heavy oil is a major source of energy in this century with a worldwide base reserve exceeding 2.5 trillion barrels. Management decisions and production strategies from thermal oil recovery processes are frequently based on reservoir simulation. A proper description of the physical properties, particularly oil viscosity, is essential in performing reliable modeling studies of fluid flow in the reservoir. We simulated cyclic steam injections on the highly viscous Hamaca oil, with a viscosity of over 10,000 cp at ambient temperature, and the production was drastically impacted by up to an order of magnitude when using improper mixing rules to describe the oil viscosity. This thesis demonstrates the importance of these mixing rules and alerts reservoir engineers to the significance of using different options simulators have built in their platforms to describe the viscosity of heavy oils. Log linear and power mixing rules do not provide enough flexibility to describe the viscosity of extra heavy oil with temperature. A recently implemented mixing rule in a commercial simulator has been studied providing satisfactory results. However, the methodology requires substantial interventions, and cannot be automatically updated. We provide guidelines to improve it and suggest more flexible mixing rules that could easily be implemented in commercial simulators. We also provide a methodology to determine the adequate time for each one of the periods in cyclic steam injection: injection, soaking and production. There is a lot of speculation in this matter and one of the objectives of this thesis is to better understand and provide guidelines to optimize oil production using proper lengths in each one of these periods. We have found that the production and injection periods should be similar in time length. Nevertheless, the production period should not be less than the injection period. On the other hand, the soaking period should be as short as possible because it is unproductive time in terms of field oil production for the well and therefore it translates into a negative cash flow for a company.
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Laboissière, Philipe 1980. "Injeção de vapor e nitrogenio na recuperação melhorada de oleo pesado." [s.n.], 2009. http://repositorio.unicamp.br/jspui/handle/REPOSIP/264286.
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Orientador: Osvair Vidal TrevisanDissertação (mestrado) - Universidade Estadual de Campinas, Faculdade de Engenharia Mecanica, Instituto de Geociencias
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Resumo: Métodos térmicos de recuperação, especialmente injeção de vapor, estão à frente da maioria dos projetos de recuperação de óleo pesado em terra. A injeção contínua e, mais recentemente, a injeção de vapor auxiliada por drenagem gravitacional permitem aumentar a recuperação. A razão do volume de vapor injetado por volume de óleo recuperado é um parâmetro decisivo na economicidade de projetos de inundação por vapor. No presente trabalho, um estudo experimental e um numérico na célula linear e um estudo numérico na célula SAGD foram desenvolvidos para entender melhor como a injeção de nitrogênio combinado com vapor contribui ao mecanismo de recuperação e para a possível redução em volume do vapor injetado. O estudo experimental foi conduzido num aparato de laboratório constituído de uma célula linear para a injeção contínua de vapor. Os estudos foram conduzidos em escala de laboratório com óleo pesado da bacia do Espírito Santo. As experiências na célula linear consistiram em injetar vapor ou vapor combinado com nitrogênio para recuperação de óleo. Nas experiências, vapor superaquecido a 170 ° C foi injetado a vazões entre 5 e 4,5 ml/min (equivalente em água fria) e nitrogênio injetado a vazões entre 50 e 180 ml/min. As principais conclusões da investigação (derivadas de cinco experimentos executados com consistentes condições operacionais) são: 1) a injeção de nitrogênio combinado com vapor acelera o início e o pico de produção de petróleo em comparação com a injeção de vapor puro; 2) a melhoria da razão vapor/óleo mostra o efeito benéfico da injeção de nitrogênio em substituição a uma fração substancial de vapor; 3) os volumes recuperados e as análises dos remanescentes apontam fatores de recuperação superiores a 45%. Pelos estudos numéricos, os resultados da modelagem da célula linear mostram frentes de vapor com comportamentos de acordo com os observados experimentalmente. No entanto, uma investigação mais aprofundada sobre o papel dos principais parâmetros utilizados para o ajuste de histórico é necessário. Os resultados simulados do SAGD - Wind Down mostram que 84% da produção do SAGD convencional podem ser recuperados com a metade de volume de vapor injetado, indicando uma redução da razão vapor/óleo de 42%.
Abstract: Thermal recovery methods, especially steam injection, are at the forefront of most onshore projects of heavy oil. The continuous injection and, recently, the steam assisted gravity drainage yield high recoveries. The ratio of the volume of steam injected per volume of produced oil is a decisive parameter in the success of steam flood projects. In the present work, an experimental and a numerical study were developed in the linear cell and a numerical study in the SAGD cell to better understand how the injection of nitrogen combined with steam contributes to the recovery mechanism, and to the possible reduction in volume of the injected steam. The experiment runs were conducted in a linear cell built for the continuous injection of steam. The studies were conducted at the lab scale using heavy oil originated from the Espírito Santo basin. The experiments in the linear cell consisted of continuously injecting steam or steam combined with nitrogen to recover oil. In the experiments, superheated steam at 170 ° C was injected at flow rates between 5 and 4,5 ml/min (cold-water equivalent) and nitrogen injected at rates between 50 and 180 ml/min. The main findings of the research (derived from five runs with consistent operating conditions) are as follows: 1) the injection of nitrogen combined with steam accelerates the start and peak of oil production compared to steam injection alone; 2) the improvement of steam oil ratio shows the beneficial effect of nitrogen injection in substitution to a substantial fraction of steam; 3) results indicates recovery factors exceeding 45%. On the numerical studies, the results from modelling of the linear cell show steam front behaviors in agreement to those observed experimentally. However, further investigation on the role of main parameters used for the history matching is necessary. The simulated results of SAGD - Wind Down shows that 84% of the production of conventional SAGD can be recovered with half of the volume of steam injected, indicating a reduction of steam oil ratio of 42%.
Mestrado
Reservatórios e Gestão
Mestre em Ciências e Engenharia de Petróleo
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Fernandes, Bruno Gimenez. "Otimização econômica de um sistema bomba de calor e reservatório térmico para aquecimento de água para fins domésticos em edifício." [s.n.], 2012. http://repositorio.unicamp.br/jspui/handle/REPOSIP/263240.
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Orientador: José Ricardo FigueiredoDissertação (mestrado) - Universidade Estadual de Campinas, Faculdade de Engenharia Mecânica
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Resumo: O objetivo do presente trabalho está na otimização econômica de um sistema com bomba de calor utilizado no aquecimento de água para banho em um edifício com reservatório térmico, para armazenamento de água quente. A otimização da bomba de calor envolve relações termodinâmicas, econômicas, de transferência de calor e mecânica dos fluidos, com o objetivo de obter o menor custo de aquecimento equivalente (CEA) da bomba de calor e do sistema. Dando continuidade a outros trabalhos já realizados na Unicamp, destacam-se neste trabalho a inclusão de perdas de carga na bomba de calor, maiores limites das variáveis não lineares a serem otimizadas, relações de transferência de calor mais realistas e a simulação do reservatório térmico de água, obtendo um volume compatível com a demanda do edifício e a eficiência da bomba de calor, durante sua utilização. No projeto preliminar, é utilizado o método de Substituição - Newton Raphson, obtendo as áreas iniciais de transferência de calor dos trocadores de calor (evaporador e condensador), o coeficiente de desempenho (COP), vazão do fluido refrigerante R- 134a (utilizado na bomba de calor), a potência do compressor, entre outros. No projeto otimizado, os valores obtidos na simulação anterior são considerados como estimativas iniciais no processo de otimização. Nesse processo o algoritmo de otimização escolhido é a Programação Quadrática Sequencial (SQP), disponível na função fmincon do MatLab'MARCA REGISTRADA'. Nas simulações do reservatório térmico, a estimativa de volume foi de 3 a 30 m3, obtendo a variação da temperatura para cada um dos volumes, é avaliado o menor trabalho médio do compressor da bomba de calor, com a variação de cada temperatura do reservatório, para que possa ser escolhido um volume adequado. Na finalização do projeto, são obtidos os melhores valores das áreas de troca de calor do evaporador e condensador, valor mínimo do CEA (função objetivo em questão) e volume do reservatório térmico, conforme condições de perdas de calor do sistema (reservatório e tubulação) e trabalhos de entrada, necessários em seu funcionamento
Abstract: The purpose of this work is the economic optimization of a system with heat pump used to heat water for bathing in a building with a thermal reservoir for hot water storage. Optimization of heat pump involves thermodynamic relations, economics, heat transfer and fluid mechanics, in order to obtain the lowest cost of heating equivalent (CEA) and heat pump system. Continuing to other work already done at Unicamp, stands out in this work to include pressure losses in the heat pump, higher limits of non-linear variables to be optimized, relations of heat transfer and more realistic simulation of the thermal reservoir water obtaining a volume compatible with the demand of the building and the efficiency of the heat pump during its use. In the preliminary design, the method is used Substiution - Newton Raphson, getting the initial areas of heat transfer of heat exchangers (evaporator and condenser), the coefficient of performance (COP), flow of refrigerant R-134a (used in Heat pump), the compressor power, among others. In the optimized design, the values obtained in previous simulation as initial estimates are considered in the optimization process. In this case the optimization algorithm chosen is the Sequential Quadratic Programming (SQP), available in the MatLab'TRADE MARK' function fmincon. In simulations of the thermal reservoir, the estimated volume was 3 to 30 m3, resulting temperature variation for each of the volumes is the lowest rated working medium of the heat pump compressor, with the temperature variation in each reservoir, can be chosen so that a suitable volume. At project completion, the best values are obtained from the areas of heat transfer from the evaporator and condenser, the minimum value of CEA (objective function in question) and the thermal reservoir volume, as conditions of heat losses from the system (tank and piping) and work input required for its operation
Mestrado
Termica e Fluidos
Mestre em Engenharia Mecânica
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Mercado, Sierra Diana Patricia 1981. "Modelo pseudocinético para a simulação numérica da combustão in-situ na escala da campo." [s.n.], 2015. http://repositorio.unicamp.br/jspui/handle/REPOSIP/265773.
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Orientador: Osvair Vidal TrevisaTese (doutorado) - Universidade Estadual de Campinas, Faculdade de Engenharia Mecânica e Instituto de Geociências
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Resumo: A combustão in-situ é um processo multiescala, multifísico que envolve simultaneamente o escoamento de fluidos no meio poroso, o equilíbrio de fases e a cinética das reações químicas. A simulação desse processo tem alcançado um elevado grau de desenvolvimento, no entanto, mecanismos básicos ainda são representados de maneira incompleta, impondo inúmeros desafios na modelagem. A dificuldade de modelar fenômenos relacionados com a combustão tem a ver com a representação do efeito da frente de combustão e a modelagem do consumo de combustível. Na combustão in-situ as reações químicas acontecem em uma zona delgada de menos de um metro de espessura, que é pequena quando comparada com a escala do reservatório de centenas ou milhares de metros. Na simulação na escala de campo, o uso de células de tamanho maior do que a zona de reação leva a erros na distribuição da temperatura. Consequentemente, a velocidade das reações não pode ser bem representada. De outro lado, os simuladores não permitem controlar a ocorrência das reações a partir da energia de ativação. Como resultado, o início das reações se torna independente da temperatura. O objetivo desta tese é desenvolver um modelo pseudocinético para a simulação numérica da combustão in-situ na escala de campo. Com o modelo pseudocinético pretende-se representar os fenômenos na zona de combustão, reduzindo o efeito do tamanho de célula. O trabalho foi desenvolvido em etapas. Primeiro foram estabelecidas as condições que o simulador deveria atender e definida a estratégia de abordagem, que foi a de desenvolver um modelo pseudocinético. Depois foi definida a metodologia de obtenção do modelo pseudocinético. Após o modelo pseudocinético concluído, este foi utilizado para a simulação de um campo de óleo pesado brasileiro submetido à combustão in-situ. O modelo pseudocinético proposto consiste em expressar a energia de ativação das reações em função da temperatura. Através do modelo, é possível restringir a ocorrência da reação de craqueamento, de modo que o início da formação do coque aconteça somente para temperaturas acima dos valores observados na zona de craqueamento. Note-se que neste cenário a quantidade de coque depositado pode ser modelada usando a reação de craqueamento, o que se constitui numa das principais contribuições do trabalho. O modelo permite manter a dependência da taxa de reação com a temperatura mediante o uso de valores de energia de ativação apropriados. Além disso, consegue-se reduzir o efeito da distribuição de temperatura mediante o controle da taxa de reação em função dos valores médios de temperatura observados nas células do modelo de simulação na escala de campo. Na simulação do piloto de combustão in-situ, o modelo pseudocinético foi obtido do ajuste progressivo dos parâmetros cinéticos das reações químicas, partindo da simulação do processo na escala de laboratório até a escala de campo. Os dados experimentais utilizados na simulação na escala de laboratório foram obtidos de um ensaio em tubo de combustão seca realizado no Laboratório de Métodos Térmicos de Recuperação do Departamento de Energia da UNICAMP. O fluido utilizado foi um óleo pesado de 15,3 °API proveniente da Bacia do Espírito Santo
Abstract: The in-situ combustion is a multi-scale, multi-physics process, involving fluid flow in porous media, thermodynamic equilibrium of the phases involved and chemical kinetics of reactions. The simulation of this process has achieved a high degree of development, however basic mechanisms are still represented incompletely, imposing numerous challenges in modeling. The issues in the combustion modeling are related with the representation of the combustion front effect and the fuel consumption modeling. Chemical reactions of the in-situ combustion process take place in a thin zone of less than a meter thick, which is small compared to the field scale of hundreds or thousands of meters. Numerical simulations at the field scale typically use grid blocks that are at least two orders of magnitude greater than that. Such divergence leads to improper representations of key aspects of the process, as the temperature distribution and the reaction kinetics. In accordance with that the reaction occurrence is not controlled by the activation energy in the simulation models. The major shortcome is on fuel deposition, a key issue in in-situ combustion, which will happen from the start, since the cracking reaction may proceed even at reservoir temperature. The objective of this thesis is to develop a new pseudokinetic model for field-scale simulation of in-situ combustion. With the pseudokinetic model meant to improve the representation of the combustion zone effects reducing the gridblock size effect. The work was carried out in stages. First establishes the conditions that the simulator should meet and defined the strategy to develop a pseudokinetic model. Then a methodology was defined for obtaining the pseudokinetic model. After the pseudokinetic model is completed, it is applied to the in-situ combustion modeling of a Brazilian heavy oil field. The models pursue the idea of making the activation energy a function of the grid block temperature. The model allows restricting the cracking reaction occurrence by the temperature, so that the beginning of the coke deposition occurs at temperatures greater than the temperature observed in the cracking zone. Note that in this scenario the cracking reaction can be used to represent the coke deposition, which constitutes one of the main contributions of this work. The model allows maintaining the dependence of reaction rate with temperature through the use of appropriate activation energy values. Furthermore, the model reduces the temperature distribution effect by controlling the reaction rate based on average temperature values observed in the field simulation model. In the simulation of the in-situ combustion pilot, the pseudokinetic model was obtained from the progressive tuning of the kinetic parameters of chemical reactions, based on the simulation of the process from the laboratory to field scale. The experimental data used in the laboratory scale simulation were obtained from a dry combustion tube test carried out at the Thermal Recovery Methods Laboratory of the Energy Department at UNICAMP. The fluid used was a 15.3 ° API heavy oil from the Espírito Santo Basin
Doutorado
Reservatórios e Gestão
Doutora em Ciências e Engenharia de Petróleo
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Barillas, Jennys Lourdes Meneses. "Estudo da recupera??o de ?leo por drenagem gravitacional assistida por inje??o de vapor." Universidade Federal do Rio Grande do Norte, 2008. http://repositorio.ufrn.br:8080/jspui/handle/123456789/15877.
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Previous issue date: 2008-02-22Steam assisted gravity drainage process (SAGD) involves two parallel horizontal wells located in a same vertical plane, where the top well is used as steam injector and the bottom well as producer. The dominant force in this process is gravitational. This improved oil recovery method has been demonstrated to be economically viable in commercial projects of oil recovery for heavy and extra heavy oil, but it is not yet implemented in Brazil. The study of this technology in reservoirs with characteristics of regional basins is necessary in order to analyze if this process can be used, minimizing the steam rate demand and improving the process profitability. In this study, a homogeneous reservoir was modeled with characteristics of Brazilian Northeast reservoirs. Simulations were accomplished with STARS , a commercial software from Computer Modelling Group, which is used to simulate improved oil recovery process in oil reservoirs. In this work, a steam optimization was accomplished in reservoirs with different physical characteristics and in different cases, through a technical-economic analysis. It was also studied a semi-continuous steam injection or with injection stops. Results showed that it is possible to use a simplified equation of the net present value, which incorporates earnings and expenses on oil production and expenses in steam requirement, in order to optimize steam rate and obtaining a higher net present value in the process. It was observed that SAGD process can be or not profitable depending on reservoirs characteristics. It was also obtained that steam demand can still be reduced injecting in a non continuous form, alternating steam injection with stops at several time intervals. The optimization of these intervals allowed to minimize heat losses and to improve oil recovery
O processo de drenagem gravitacional com inje??o cont?nua de vapor (SAGD) envolve dois po?os horizontais paralelos localizados em uma mesma vertical, onde o po?o superior ? usado como injetor de vapor e o inferior como produtor. A for?a dominante neste processo ? a gravitacional. Este m?todo de recupera??o avan?ada tem sido demonstrado ser economicamente vi?vel em projetos comerciais de recupera??o de petr?leo pesado e extra pesado, mas ainda n?o foi implementado no Brasil. O estudo desta tecnologia em reservat?rios com caracter?sticas das bacias regionais ? necess?rio para analisar como se ad?qua o processo para minimizar a demanda de vapor obtendo a maior rentabilidade do processo. Neste estudo foi usado um modelo homog?neo com caracter?sticas de reservat?rios do Nordeste Brasileiro. As simula??es foram realizadas em um programa comercial da Computer Modelling Group , o STARS , m?dulo usado para realizar estudos de m?todos de recupera??o avan?ada de reservat?rios de ?leo. Neste trabalho, foi realizada uma otimiza??o do vapor em reservat?rios com diferentes caracter?sticas f?sicas e em diferentes cen?rios, atrav?s de uma an?lise t?cnico-econ?mica. Tamb?m foi estudada a inje??o de vapor semi-cont?nua ou com paradas. Os resultados obtidos mostraram que ? poss?vel utilizar uma equa??o simplificada do valor presente l?quido, que incorpora os ganhos e gastos na produ??o de ?leo e os gastos na inje??o de vapor, para otimizar a demanda do vapor obtendo um maior valor presente l?quido no processo. Observou-se que o m?todo (SAGD) pode ser ou n?o rent?vel dependendo das caracter?sticas do reservat?rio. Encontrou-se tamb?m que a necessidade de vapor pode ainda ser diminu?da utilizando esquemas de inje??o de vapor com paradas em intervalos de tempo otimizados, e isto permitiu minimizar as perdas de calor e melhorar a recupera??o.
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Jobard, Emmanuel. "Modélisation expérimentale du stockage géologique du CO2 : étude particulière des interfaces entre ciment de puits, roche reservoir et roche couverture." Thesis, Université de Lorraine, 2013. http://www.theses.fr/2013LORR0013/document.
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Dans le cadre du stockage géologique de gaz acides, il est impératif de garantir l'intégrité des matériaux sollicités afin d'assurer un confinement pérenne du fluide injecté. Le but de ce travail de thèse est d'étudier, par le biais de modélisations expérimentales, les phénomènes pouvant être responsables de la déstabilisation du système et qui peuvent conduire à des fuites du gaz stocké. Le premier modèle expérimental, appelé COTAGES a permis d'étudier les effets de la déstabilisation thermique provoquée par l'injection d'un gaz à température ambiante dans un réservoir chaud. Ce dispositif a permis de mettre en évidence un transfert de matière important depuis la zone froide (30°C) vers la zone chaude (100°C) conduisant à des modifications des propriétés pétrophysiques. Ces résultats soulignent l'importance de la température d'injection sur la conservation des propriétés d'injectivité du système. Le second modèle, appelé "Sandwich" a permis d'étudier le comportement de l?interface entre la roche couverture (argilite COX) et le ciment de puits. Les expériences batch du modèle Sandwich en présence de CO2 ont permis de mettre en évidence une fracturation de l'interface provoquée par la carbonatation précoce du ciment. Ces résultats soulignent l'importance de l'état initial de la roche couverture dans la séquestration du fluide injecté. Le troisième modèle expérimental est le modèle MIRAGES. Ce dispositif innovant permet d'injecter en continu un flux de CO2 dans un échantillon. Les résultats ont mis en évidence un colmatage partiel de la porosité inter-oolithe à proximité du puits d'injection, ainsi qu'une carbonatation du ciment sous la forme d'un assemblage calcite/aragoniteIn the framework of the CO2 storage, it is crucial to ensure the integrity of the solicited materials in order to guarantee the permanent confinement of the sequestrated fluids. Using experimental simulation the purpose of this work is to study the mechanisms which could be responsible for the system destabilization and could lead CO2 leakage from the injection well. The first experimental model, called COTAGES allows studying the effects of the thermal destabilisation caused by the injection of a fluid at 25°C in a hotter reservoir (submitted to the geothermal gradient). This device allows demonstrating an important matter transfer from the cold area (30°C) toward the hot area (100°C). These results highlight the importance of the injection temperature on the injectivity properties and on the possible petrophysical evolutions of the near well. The second model, called ?Sandwich?, allow studying the behaviour of the interface between caprock (COX argillite) and well cement. Indeed, interfaces between the different rock and the well materials represent a weakness area (differential reactivity, fracturing?). Batch experiments carried out with this device in presence of CO2 show the fracturing of the interface caused by the early carbonation of the cement. The third experimental model, called MIRAGES is an innovative device which allows injecting continuously CO2 in a core sample. Samples made of Lavoux limestone and well cement reproduce the injection well at 1/20 scale. Results show a partial filling of the inter-oolithic porosity close to the injection well, and also the carbonation of the cement according to an assemblage of calcite/aragonite
Book chapters on the topic "Thermal reservoir simulation"
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Paterson, Duncan. "EoS-Based Thermal Reservoir Simulation." In Springer Theses, 125–50. Cham: Springer International Publishing, 2019. http://dx.doi.org/10.1007/978-3-030-11787-0_5.
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Üneş, Fatih, Mustafa Demirci, and Hakan Varçin. "3-D Numerical Simulation of a Real Dam Reservoir: Thermal Stratified Flow." In Advances in Hydroinformatics, 377–94. Singapore: Springer Singapore, 2015. http://dx.doi.org/10.1007/978-981-287-615-7_26.
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Zhu, Yujie, Xiaoli Liu, Enzhi Wang, and Jianwen Zhong. "Simulation on Reservoir-Induced Seismicity Considering Thermo-Hydro-Mechanical Couplings." In Springer Series in Geomechanics and Geoengineering, 377–83. Cham: Springer International Publishing, 2018. http://dx.doi.org/10.1007/978-3-319-99670-7_47.
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Fang, Huo-Lang. "A Fully Coupled Thermo-Hydro-Mechanical Model For Methane Hydrate Reservoir Simulations." In Advances in Environmental Geotechnics, 455–61. Berlin, Heidelberg: Springer Berlin Heidelberg, 2010. http://dx.doi.org/10.1007/978-3-642-04460-1_37.
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Wu, Wenwei, Liguo Zhong, Xiaodong Han, Lipeng Tong, Cheng Wang, Caixia Wang, Bingyan Liu, Jianbin Liu, Tongchun Hao, and Shuang Huang. "Study on Gas Channeling Regularity and Anti-channeling Measures of Multi-component Thermal Fluid Huff and Puff for Xinjiang Heavy Oil Reservoirs." In Computational and Experimental Simulations in Engineering, 933–53. Cham: Springer International Publishing, 2019. http://dx.doi.org/10.1007/978-3-030-27053-7_81.
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"Biology and Management of Inland Striped Bass and Hybrid Striped Bass." In Biology and Management of Inland Striped Bass and Hybrid Striped Bass, edited by Jessica S. Thompson and James A. Rice. American Fisheries Society, 2013. http://dx.doi.org/10.47886/9781934874363.ch5.
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<em>Abstract</em>.—Warm epilimnetic temperatures and hypolimnetic hypoxia during summer stratification have been linked to poor growth and condition of inland striped bass <em>Morone saxatilis</em>. Contrary to expectations, however, growth occurs in some reservoirs with intense temperature–oxygen stratification in which hypoxia forces striped bass into temperatures well above their preferred range. One potential explanation for this apparent contradiction is that high forage availability may mediate the energetic costs of exposure to warm summer temperatures in some systems. To test this hypothesis, we assessed the relative influence of thermal experience and food consumption on growth of striped bass in Badin Lake and Lake Norman, North Carolina, using bioenergetics model simulations. Badin Lake is eutrophic with striped bass restricted by hypoxia to warm temperatures in the summer, but striped bass experience modest positive growth over the summer and substantial annual growth. Lake Norman is oligotrophic and striped bass are restricted to warm temperatures by hypoxia for a shorter period, but they experience almost no summer growth and minimal annual growth after age 3. Model simulations showed that Badin Lake striped bass ages 1–4 achieved high food consumption rates during the summer that continued into the fall as temperatures cooled, allowing for rapid fall growth. Lake Norman striped bass ages 1–5 experienced lower consumption rates over the summer and fall. Consumption was not sufficient to allow larger striped bass to allocate energy to growth over the summer, and these fish did not experience any season with a combination of cool temperatures and high food consumption. Habitat exchange simulations modeled how much the growth of a particular size fish in one reservoir might change if it had experienced the temperatures or food consumption of a similar sized fish in the other reservoir. These simulations showed that the relative effect of food consumption on striped bass growth was three times that of exposure temperature in the first year of the study and 37 times that of temperature in the second year. Poor striped bass growth and condition is not, therefore, linked solely to poor physical habitat. Rather, management of reservoir striped bass populations will be improved by balancing demand for and availability of prey resources for striped bass, and this balance will be especially important in reservoirs where summer hypoxia forces fish into warm temperatures that increase metabolic costs.
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Gurgel, Antonio R., Anthony A. R. Diniz, Edson A. Araújo, Davi M. S. B. Lima, Marcos A. F. Rodrigues, Wison da Mata, and Tarcilio V. Dutra. "Study of thermal efficiency in heavy oil reservoirs submitted to steam injection by using numerical simulation." In Computer Aided Chemical Engineering, 1719–24. Elsevier, 2016. http://dx.doi.org/10.1016/b978-0-444-63428-3.50291-5.
Full textConference papers on the topic "Thermal reservoir simulation"
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Stone, T. W., J. Bennett, D. H. S. Law, and J. A. Holmes. "Thermal Simulation with Multisegment Wells." In SPE Reservoir Simulation Symposium. Society of Petroleum Engineers, 2001. http://dx.doi.org/10.2118/66373-ms.
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Zhu, Zhouyuan, Marco Roberto Thiele, and Margot Geertrui Gerritsen. "Thermal Streamline Simulation: Steam Floods." In SPE Reservoir Simulation Symposium. Society of Petroleum Engineers, 2011. http://dx.doi.org/10.2118/139501-ms.
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Naccache, P. F. "A Fully-Implicit Thermal Reservoir Simulator." In SPE Reservoir Simulation Symposium. Society of Petroleum Engineers, 1997. http://dx.doi.org/10.2118/37985-ms.
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Shi, Xundan, Yih-Bor Chang, Mathieu Muller, Eguono Obi, and Kok-Thye Lim. "A General Unstructured Grid, Parallel, Fully Implicit Thermal Simulator and Its Application for Large Scale Thermal Models." In SPE Reservoir Simulation Symposium. Society of Petroleum Engineers, 2009. http://dx.doi.org/10.2118/119172-ms.
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Varavei, Abdoljalil, and Kamy Sepehrnoori. "An EOS-Based Compositional Thermal Reservoir Simulator." In SPE Reservoir Simulation Symposium. Society of Petroleum Engineers, 2009. http://dx.doi.org/10.2118/119154-ms.
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Zhu, Zhouyuan, Margot Geertrui Gerritsen, and Marco Roberto Thiele. "Thermal Streamline Simulation for Hot Water Flooding." In SPE Reservoir Simulation Symposium. Society of Petroleum Engineers, 2009. http://dx.doi.org/10.2118/119200-ms.
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Chempath, Shaji, Huafei Sun, and Kjetil Haugen. "Optimization Based Isenthalpic Flash for Thermal Reservoir Simulations." In SPE Reservoir Simulation Conference. Society of Petroleum Engineers, 2017. http://dx.doi.org/10.2118/182702-ms.
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Stone, Terry Wayne, and James S. Nolen. "Practical and Robust Isenthalpic/Isothermal Flashes for Thermal Fluids." In SPE Reservoir Simulation Symposium. Society of Petroleum Engineers, 2009. http://dx.doi.org/10.2118/118893-ms.
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Zhou, Yifan, Gary Li, and Vito Zapata. "A Natural Variable Well Model for Advanced Thermal Simulation." In SPE Reservoir Simulation Conference. Society of Petroleum Engineers, 2019. http://dx.doi.org/10.2118/193835-ms.
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Zhu, Di, and Ryosuke Okuno. "Analysis of Narrow-Boiling Behavior for Thermal Compositional Simulation." In SPE Reservoir Simulation Symposium. Society of Petroleum Engineers, 2015. http://dx.doi.org/10.2118/173234-ms.
Full textReports on the topic "Thermal reservoir simulation"
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Kamath, V., and S. Godbole. Development of a reservoir simulation for thermal recovery of heavy oils/tar sands in the presence of gas hydrates. Office of Scientific and Technical Information (OSTI), October 1988. http://dx.doi.org/10.2172/5585057.
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Kamath, V., and S. Godbole. Development of a reservoir simulation for thermal recovery of heavy oils/tar sands in the presence of gas hydrates. Office of Scientific and Technical Information (OSTI), October 1988. http://dx.doi.org/10.2172/5585057.
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