Download or read book Coupling of Reservoir Simulator and a Wellbore Simulator for Geothermal Applications written by and published by . This book was released on 1993 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Coupling of the HOLA Wellbore Simulator with TOUGH2 Reservoir Simulator written by Ashish Bhat and published by . This book was released on 2005 with total page 250 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book A Coupled Wellbore reservoir Simulator to Model Multiphase Flow and Temperature Distribution written by Peyman Pourafshary and published by . This book was released on 2007 with total page 570 pages. Available in PDF, EPUB and Kindle. Book excerpt: Hydrocarbon reserves are generally produced through wells drilled into reservoir pay zones. During production, gas liberation from the oil phase occurs due to pressure decline in the wellbore. Thus, we expect multiphase flow in some sections of the wellbore. As a multi-phase/multi-component gas-oil mixture flows from the reservoir to the surface, pressure, temperature, composition, and liquid holdup distributions are interrelated. Modeling these multiphase flow parameters is important to design production strategies such as artificial lift procedures. A wellbore fluid flow model can also be used for pressure transient test analysis and interpretation. Considering heat exchange in the wellbore is important to compute fluid flow parameters accurately. Modeling multiphase fluid flow in the wellbore becomes more complicated due to heat transfer between the wellbore fluids and the surrounding formations. Due to mass, momentum, and energy exchange between the wellbore and the reservoir, the wellbore model should be coupled with a numerical reservoir model to simulate fluid flow accurately. This model should be non-isothermal to consider the effect of temperature. Our research shows that, in some cases, ignoring compositional effects may lead to errors in pressure profile prediction for the wellbore. Nearly all multiphase wellbore simulations are currently performed using the "black oil" approach. The primary objective of this study was to develop a non-isothermal wellbore simulator to model transient fluid flow and temperature and couple the model to a reservoir simulator called General Purpose Adaptive Simulator (GPAS). The coupled wellbore/reservoir simulator can be applied to steady state problems, such as production from, or injection to a reservoir as well as during transient phenomena such as well tests to accurately model wellbore effects. Fluid flow in the wellbore may be modeled either using the blackoil approach or the compositional approach, as required by the complexity of the fluids. The simulation results of the new model were compared with field data for pressure gradients and temperature distribution obtained from wireline conveyed pressure recorder and acoustic fluid level measurements for a gas/oil producer well during a buildup test. The model results are in good agreement with the field data. Our simulator gave us further insights into the wellbore dynamics that occur during transient problems such as phase segregation and counter-current multiphase flow. We show that neglecting these multiphase flow dynamics would lead to unreliable results in well testing analysis.

Download or read book Geothermal Well Test Analysis written by Sadiq J. Zarrouk and published by Academic Press. This book was released on 2019-04-30 with total page 366 pages. Available in PDF, EPUB and Kindle. Book excerpt: Geothermal Well Test Analysis: Fundamentals, Applications and Advanced Techniques provides a comprehensive review of the geothermal pressure transient analysis methodology and its similarities and differences with petroleum and groundwater well test analysis. Also discussed are the different tests undertaken in geothermal wells during completion testing, output/production testing, and the interpretation of data. In addition, the book focuses on pressure transient analysis by numerical simulation and inverse methods, also covering the familiar pressure derivative plot. Finally, non-standard geothermal pressure transient behaviors are analyzed and interpreted by numerical techniques for cases beyond the limit of existing analytical techniques. Provides a guide on the analysis of well test data in geothermal wells, including pressure transient analysis, completion testing and output testing Presents practical information on how to avoid common issues with data collection in geothermal wells Uses SI units, converting existing equations and models found in literature to this unit system instead of oilfield units

Download or read book Development of a Coupled Wellbore reservoir Compositional Simulator for Horizontal Wells written by Mahdy Shirdel and published by . This book was released on 2010 with total page 402 pages. Available in PDF, EPUB and Kindle. Book excerpt: Two-phase flow occurs during the production of oil and gas in the wellbores. Modeling this phenomenon is important for monitoring well productivity and designing surface facilities. Since the transient time period in the wellbore is usually shorter than reservoir time steps, stabilized flow is assumed in the wellbore. As such, semi-steady state models are used for modeling wellbore flow dynamics. However, in the case that flow variations happen in a short period of time (i.e., a gas kick during drilling) the use of a transient two-phase model is crucial. Over the last few years, a number of numerical and analytical wellbore simulators have been developed to mimic wellbore-reservoir interaction. However, some issues still remain a concern in these studies. The main issues surrounding a comprehensive wellbore model consist of fluid property calculations, such as black-oil or compositional models, governing equations, such as mechanistic or correlation-based models, effect of temperature variation and non-isothermal assumption, and methods for coupling the wellbore to the reservoir. In most cases, only standalone wellbore models for blackoil have been used to simulate reservoir and wellbore dynamic interactions. Those models are based on simplified assumptions that lead to an unrealistic estimation of pressure and temperature distributions inside the well. In addition, most reservoir simulators use rough estimates for the perforation pressure as a coupling condition between the wellbore and the reservoir, neglecting pressure drops in the horizontal section. In this study, we present an implementation of a compositional, pseudo steady-state, non-isothermal, coupled wellbore-reservoir simulator for fluid flow in wellbores with a vertical section and a horizontal section embedded on the producing reservoir. In addition, we present the implementation of a pseudo-compositional, fully implicit, transient two-fluid model for two-phase flow in wellbores. In this model, we solve gas/liquid mass balance, gas/liquid momentum balance, and two-phase energy equations in order to obtain the five primary variables: liquid velocity, gas velocity, pressure, holdup and temperature. In our simulation, we compared stratified, bubbly, intermittent flow effects on pressure and temperature distributions in either a transient or steady-state condition. We found that flow geometry variation in different regimes can significantly affect the flow parameters. We also observed that there are significant differences in flow rate prediction between a coupled wellbore-reservoir simulator and a stand-alone reservoir simulator, at the early stages of production. The outcome of this research leads to a more accurate and reliable simulation of multiphase flow in the wellbore, which can be applied to surface facility design, well performance optimization, and wellbore damage estimation.

Download or read book Development of a Fully Integrated Equation of State Compositional Hydraulic Fracturing and Reservoir Simulator written by Shuang Zheng and published by . This book was released on 2021 with total page 928 pages. Available in PDF, EPUB and Kindle. Book excerpt: Numerical modeling plays a key role in assessing, developing, and managing energy resources (such as oil, gas and heat) from subsurface formations. Fluids are injected into wellbores during hydraulic fracturing, water flooding, parent well pre-loading, and improved oil recovery. Oil, gas and water are produced back to the surface during flowback, primary/secondary/tertiary production, and geothermal operations. Results from modeling these subsurface energy resources assist engineers and geologists in the decision-making process. Geomechanics, fluid/solid flow, and heat transport are coupled in the reservoir, fracture, and wellbore domains. The purpose of this dissertation is to develop integrated hydraulic fracturing and reservoir simulator that can accurately model multi-component, multi-phase fluid flow, geomechanics, fracture propagation and thermal processes in the reservoir, fracture and wellbore domains. In this dissertation, fully coupled reservoir, fracture, and wellbore domains are modeled. Geomechanics, fluid flow, and heat transport are modeled in an integrated manner in each domain and between each domain. Thermo-poro-elasticity, fracture opening/closing, and fracture propagation are modeled based on the stresses and strains computed in the domain. Four flow types including single-phase flow, multi-phase black-oil flow, multi-phase compositional flow, and water-steam two-phase flow are developed for different applications. Temperature and enthalpy formulations are developed to model the energy balance within the fully coupled system. A novel proppant transport model formulation which couples fracture opening/closing has also been developed. The governing equations are discretized in space using the finite volume/area methods. Multiple fully implicit Newton solvers have been developed to solve different sets of nonlinear systems of equations. A fully distributed memory parallelization workflow is constructed. The simulator is also coupled with simpler (analytical and DDM) fracturing models to achieve shorter run times. The modeling capability of the simulator has been demonstrated in the dissertation through many example applications. Typical applications of the simulator include multi-stage, multi-cluster, hydraulic fracture propagation, proppant settling and fracture closure analysis, mini-frac analysis, parent-child well interference, fracture monitoring, reservoir cooling and induced fracture propagation from water injectors, production analysis, gas huff-n-puff injection, improved oil recovery, geothermal reservoir production, and enhanced geothermal system analysis. These applications demonstrate the wide variety of problems that our simulator can be used to model

Download or read book Renewable Energy Systems written by Martin Kaltschmitt and published by Springer. This book was released on 2012-12-06 with total page 1898 pages. Available in PDF, EPUB and Kindle. Book excerpt: Humanity is facing a steadily diminishing supply of fossil fuels, causing researchers, policy makers, and the population as a whole to turn increasingly to alternative and especially renewable sources of energy to make up this deficit. Gathering over 80 peer-reviewed entries from the Encyclopedia of Sustainability Science and Technologies, Renewable Energy Systems provides an authoritative introduction to a wide variety of renewable energy sources. State-of-the-art coverage includes geothermal power stations, ocean energy, renewable energy from biomass, waste to energy, and wind power. This comprehensive, two-volume work provides an excellent introduction for those entering these fields, as well as new insights for advanced researchers, industry experts, and decision makers.

Download or read book A Coupled Geomechanics and Reservoir Simulator and Its Application to Reservoir Development Strategies written by Chao Gao (Ph. D.) and published by . This book was released on 2019 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt: A new Coupled Geomechanics and Reservoir Simulator, CGRS, and a wellbore stability model, WSM, are utilized to provide dynamic infill drilling strategies - where to drill, when to drill and how to drill - that greatly improve upon the traditional constant stress path method. The stress path, defined as the ratio of the change of far-field horizontal stress to change of pore pressure, has a profound influence on wellbore stability while drilling in a depleted reservoir. Based on the common assumptions of uniaxial strain and homogenous depletion, the traditional analytical stress path solution is a function of Biot's coefficient and Poisson's ratio. Pore pressure depletion, however, is location and time dependent, not homogeneous. Thus, the objective of this study is to analyze the wellbore stability of infill wells with a coupled geomechanics and reservoir simulator. Two wellbore stability models, first a conventional wellbore stability model (CWSM) and second a Coupled Geomechanics and Reservoir Simulator Wellbore Stability Model (CGRS-WSM), were developed. For CWSM, the analytical stress path solution is applied to get updated far-field horizontal stresses. CGRS-WSM, however, does not require changes in far-field horizontal stress with pressure depletion. Rather, CGRS gives the stress field of the whole reservoir, and those stress components at a specific point in Cartesian coordinates are used directly in CGRS-WSM to calculate the mud weight window. For CGRS, an in-house coupled geomechanics and reservoir simulator is developed that considers lateral displacements and inhomogeneous depletion of the reservoir. In addition, an Abaqus model is also developed to analyze the influence of plasticity and stress arching on pore pressure and stress change during depletion, which are used in CGRS-WSM to investigate wellbore stability. Different shear failure criteria are utilized in a new CGRS wellbore stability model. The upper bounds of shear failure are given by Drucker-Prager Inscribes and Griffith Theory, while the lower bound is given by Drucker-Prager Circumscribe. Several case studies for drilling in a depleted reservoir compare CWSM with CGRS-WSM. There is a significant difference in the two maximum mud weights, with operational consequences, for example, as related to potential lost circulation problems. For some examples, the narrower mud weight from CGRS-WSM, as compared to CWSM, is a more realistic unsafe region warning. CGRS-WSM can quantify the influence of azimuth on the minimum and the maximum mud weight during the depletion when initial maximum horizontal stress equals minimum horizontal stress. In addition, CGRS-WSM can give the output of a location-dependent mud weight map for the entire reservoir. Neither of the above two functions can be realized by a conventional wellbore stability model. The CGRS-WSM in this work is a significant step in drilling infill wells in depleted zones, owing to its ability to quantify horizontal displacements, inhomogeneous depletion, plasticity, and stress arching, which cannot be done with the traditional analytical stress path procedure. Moreover, the connection of a coupled geomechanics and reservoir simulator with a wellbore stability simulator provides dynamic information useful to quantify where to drill, when to drill and how to drill. This new model can be used to investigate 'what if' scenarios, parameter sensitivity studies, case study reviews, and previously drilled well critiques

Download or read book Computational Models for CO2 Geo sequestration Compressed Air Energy Storage written by Rafid Al-Khoury and published by CRC Press. This book was released on 2014-04-17 with total page 566 pages. Available in PDF, EPUB and Kindle. Book excerpt: A comprehensive mathematical and computational modeling of CO2 Geosequestration and Compressed Air Energy StorageEnergy and environment are two interrelated issues of great concern to modern civilization. As the world population will soon reach eight billion, the demand for energy will dramatically increase, intensifying the use of fossil fuels. Ut

Download or read book Thermo Hydro Mechanical THM coupled simulations of innovative enhanced geothermal systems for heat and electricity production as well as energy storage written by Muhammad Haris and published by Cuvillier Verlag. This book was released on 2022-08-05 with total page 175 pages. Available in PDF, EPUB and Kindle. Book excerpt: Enhanced geothermal systems (EGSs) evolved from the hot dry rock can provide a significant amount of energy while shifting towards negligible carbon emission. In order to investigate some important issues related to EGS, several scenarios have been analyzed using powerful numerical tools (FLAC3Dplus and TOUGH2MP-TMVOC). While conducting multiple hydraulic fracturing, it is observed that the newly created successive fracture’s configuration highly depends on the previous one under the influence of stress shadow. Therefore, the assumption of using similar multiple fracture geometries and shapes for energy exploitation may lead to erroneous estimations. A case study has been performed further using the engineering data of the GeneSys project in the North German Basin. Numerous scenarios have been investigated, and the optimized EGS project is proposed, whose installed power capacity of one side of the injection well declines from 7.17 MW to 5.08 MW over 30 years. Moreover, the Levelized cost of electricity is calculated at 5.46 c$/kWh, which is quite economical compared to the current electricity price. Finally, an innovative concept of regenerative EGS is proposed by storing surplus renewable energy in multiple hydraulic fractures that can reduce the reservoir temperature reduction rate. The results of continuous injection/production cycles depicted that a regenerative EGS could be achieved in reality.

Download or read book Utilities and Geothermal written by Geothermal Resources Council and published by . This book was released on 1993 with total page 572 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Progress in Exploration Development and Utilization of Geothermal Energy written by Yinhui Zuo and published by Frontiers Media SA. This book was released on 2022-09-21 with total page 364 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Geothermal Power Plants written by Ronald DiPippo and published by Butterworth-Heinemann. This book was released on 2012-04-24 with total page 625 pages. Available in PDF, EPUB and Kindle. Book excerpt: Geothermal energy is a key component of the renewable energy landscape. This is the only book that places engineering principles at the heart of its approach, with complete coverage of the basis for the design of geothermal power systems.

Download or read book A Multi feedzone Geothermal Wellbore Simulator written by Grimur Bjornsson and published by . This book was released on 1986 with total page 234 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Development of an Integrated Compositional Wellbore reservoir Simulator for Flow Assurance Problems written by Ali Abouie and published by . This book was released on 2019 with total page 710 pages. Available in PDF, EPUB and Kindle. Book excerpt: Flow assurance problems such as asphaltene and geochemical scale precipitation and deposition are among the major operational challenges encountered during oil production. The variations in thermodynamic conditions such as pressure, temperature, and/or fluid composition can result in formation and deposition of solid particles (e.g., asphaltene and scale particles) in the reservoir and wellbore. Although asphaltene and scale precipitation and deposition can occur in the reservoir and near-wellbore regions, this problem is mainly observed in the production wells. Precipitation and deposition of asphaltene and scale particles in the wellbore can cause partial or total plugging of tubing. Asphaltene and scale precipitation from the reservoir fluids can also cause formation damage problems (i.e., pore throat plugging and wettability alteration) in the reservoir and near-wellbore region. These factors affect the economics of the project by lowering the production rate and requiring remediation. Application of improved oil recovery techniques such as waterflooding and miscible gas flooding has also increased the chances of scale and asphaltene formation in the wellbore and near-wellbore region. In this dissertation, we developed an integrated compositional coupled wellbore-reservoir simulator to accurately predict the detrimental effects of asphaltene and scale deposition on production performance of the oilfields. The simulation results illustrate the time and the location at which asphaltene and scale deposition damage the efficiency and productivity of the production wells. This prediction is highly crucial to monitor the production performance of the field, to optimize the field operating condition which leads to minimum asphaltene or scale formation, and to propose the effective remediation techniques. The developed wellbore model has the flexibility to work in standalone mode or in conjunction with the reservoir simulator. To accurately model the asphaltene phase behavior as a function of pressure, temperature, and hydrocarbon fluid composition, PC-SAFT equation-of-state is implemented into a non-isothermal, multiphase, multi-component compositional wellbore simulator (UTWELL). PC-SAFT models asphaltene precipitation by performing a three-phase flash calculation to determine the formation of the second-liquid phase or asphaltene-rich phase. Flocculation and deposition models are also integrated with the thermodynamic models to mimic the dynamics of asphaltene deposition during multiphase flow in the wellbore. In addition, the computational time of the reservoir simulator (UTCOMP) with PC-SAFT EOS was improved by parallelizing the phase behavior module. To investigate the dynamics of asphaltene deposition under fluid flow condition, several mechanisms such as asphaltene precipitation, asphaltene deposition, porosity and permeability reduction, wettability alteration, and viscosity modification were included in the developed model. For mechanistic modeling of scale deposition in the wellbore, a detailed procedure is presented through which a comprehensive geochemical package, IPhreeqc, is integrated within the wellbore simulator. The integrated model has the capability to model reversible, irreversible, and ion exchange reactions under non-isothermal, non-isobaric, and local equilibrium or kinetic conditions inside the wellbore. In addition, the effects of hydrocarbon components and weak acids dissolutions in the aqueous phase are included in the integrated model to accurately predict scale deposition profile. Moreover, the developed wellbore model and the reservoir simulator were coupled to investigate the effects of key parameters such as pressure, temperature, hydrocarbon fluid composition, aqueous phase composition, breakthrough time, particle transportation, and flow dynamics on asphaltene/scale precipitation and deposition. The coupled wellbore-reservoir model can also be applied to achieve the optimum solution (e.g., operating condition, injection water composition, injection gas composition) with minimum asphaltene/scale problems in the production system. Finally, continuous chemical injection model was implemented within the wellbore simulator to investigate the effectiveness of chemical injection on prevention of asphaltene precipitation. The simulation results revealed that proper selection of the type and injection rate of solvent can minimize asphaltene deposition in the wellbore

Download or read book Coupled Modeling of Dynamic Reservoir Well Interactions Under Liquid loading Conditions written by Akkharachai Limpasurat and published by . This book was released on 2014 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: Liquid loading in a gas well occurs when the upward gas flow rate is insufficient to lift the coproduced liquid to the surface, which results in an accumulation of liquid at the bottom of the well. The liquid column in the tubing creates backpressure on the formation, which decreases the gas production rate and may stop the well from flowing. To model these phenomena, the dynamic interaction between the reservoir and the wellbore must be characterized. Due to wellbore phase re-distribution and potential phase-reinjection into the reservoir, the boundary conditions must be able to handle changing flow direction through the connections between the two subsystems. This study presents a new formulation of the wellbore boundary condition used in reservoir simulators. The boundary condition uses the new state variable, the multiphase zero flow pressure (MPZFP, p0), to determine flow direction in the connection grid block. If the wellbore pressure is less than the p0, the connection is producing; otherwise, it is injecting. The volumetric proportion of the flow is always determined by the upstream side. The new reservoir simulator is used in coupled modeling associated with liquid loading phenomena. The metastable condition can be modeled in a simple manner without any limiting assumptions and numerical stability problems. We also applied this simulator for history matching of a gas well flowing with an intermittent production strategy. A basic transient wellbore model was developed for this purpose. The long-term tubinghead pressure (THP) history can be traced by our coupled simulation. Our modeling examples indicated that, the new wellbore boundary condition is suitable in modeling the dynamic interactions between reservoir and wellbore subsystems during liquid loading. The flow direction through the connection grid block can be automatically detected by our boundary condition without numerical difficulty during the course of the simulation. In addition, the capillary pressure can be accounted at the connection grid blocks when applying our new formulation in the reservoir simulator. The electronic version of this dissertation is accessible from http://hdl.handle.net/1969.1/151699

Download or read book Integration of Numerical and Machine Learning Protocols for Coupled Reservoir wellbore Models written by Venkataramana Putcha and published by . This book was released on 2017 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: As the reservoir pressure declines with time, many of the wells do not have adequate bottom-hole pressure to carry the fluids to the surface. Under such circumstances, artificial lift mechanisms must be employed. Amongst various artificial lift mechanisms, a significant proportion of wells utilize the gas-lift mechanism, which is an extension of the natural flow. In gas-lift implementation, high pressure gas is injected into the wellbore through a valve, where injected gas supports production by altering the composition and reducing the density, and increasing the velocity of the produced fluids. In order to design a gas-lift system, a study of the inflow performance of the fluid from the reservoir into the wellbore, combined with the outflow performance of the fluids from the bottom of the wellbore to the surface is necessary. For this purpose, existing technologies for optimization of gas-lift systems predominantly use empirical correlations in order to reduce the computational overhead. These systems use a single-equation based inflow performance relations and black-oil outflow performance correlations that have restricted applicability in systems where the fluid composition varies spatially and temporally. The contemporary protocols consider the oil flow rate, water cut and formation gas-liquid ratio and well productivity index at a given instant of time to calculate the optimal quantity of gas lift injection. Due to this methodology, the effects of pressure decline and subsequent variations in well performance are not adequately captured. This results in a solution which determines the maximum liquid flow rate expected for a given gas lift injection rate only for the instantaneous period at which the study has been performed. This optimal gas lift injection rate may or may not provide the maximum total output of oil over the producing life of the well. As a first step, a compositional coupled numerical reservoir and wellbore hydraulics models has been developed as a part of this work. These hard-computing tools simulate the variations in composition, pressure and production profiles of a gas lift well and its associated reservoir from inception to abandonment. One more advantage of this method is that it can predict the future performance of a well with or without the details of well production history. This capability can be useful when gas lift is introduced in a well immediately after its completion post a drilling or a work-over job. Soft computing tools have gained popularity in the petroleum industry due to their speed, simplicity, wide range of applicability, capacity to identify patterns and ability to provide inverse solutions. The fully numerical coupled reservoir-wellbore simulator developed is computationally expensive. In order to develop a faster system, firstly, an ANN based wellbore hydraulics tool is developed and coupled with the numerical reservoir simulator. The data utilized for training the ANN tool was generated using the numerical wellbore hydraulics tool. Both the numerical and ANN wellbore hydraulics models were validated against cases from the field and another compositional numerical model from the literature. The average relative deviation with respect to field data was observed to be 2.2% and 2.4% respectively for the ANN and numerical wellbore hydraulics model, respectively. When compared against another compositional numerical model, the average relative deviation for the ANN based model was observed to be between 3.3% and 7.1%, while it was between 2.3% and 8.1% for the numerical model developed in this work. While the ANN based wellbore hydraulics model maintained the accuracy of the numerical model, it outperformed its counterpart the numerical model, by four orders of magnitude in terms of speed-up. The ANN based wellbore model was also coupled with the numerical reservoir simulator. This resultant model which involves a coupled numerical-ANN system is faster than the fully numerical coupled system by about 160 times. This coupled tool was used to generate a gas lift database of cumulative oil production of a well with various reservoir and wellbore operating conditions under a range of operating gas lift injection depths and flow rates. This database was used to develop an ANN based gas lift model that is capable of generating performance curves plotting total oil produced during the producing life of a well as a function of gas lift injection rate. Blind testing of the ANN gas lift model showed an average absolute error of 16.6 % with respect to the predictions of the coupled numerical-ANN reservoir wellbore model. This fully ANN based gas lift model provided a speed-up by four orders of magnitude with respect to the coupled numerical-ANN based model. Hence, a fast, robust and versatile model has been developed for maximizing total primary oil recovery using gas lift optimization through integration of numerical and neuro-simulation.