Literatura académica sobre el tema "Compositional hydraulic fracturing model"

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Artículos de revistas sobre el tema "Compositional hydraulic fracturing model"

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Friehauf, Kyle E., and Mukul M. Sharma. "A New Compositional Model for Hydraulic Fracturing With Energized Fluids." SPE Production & Operations 24, no. 04 (2009): 562–72. http://dx.doi.org/10.2118/115750-pa.

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Ribeiro, Lionel H., and Mukul M. Sharma. "A New 3D Compositional Model for Hydraulic Fracturing With Energized Fluids." SPE Production & Operations 28, no. 03 (2013): 259–67. http://dx.doi.org/10.2118/159812-pa.

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Bulgakova, Guzel T., Andrey R. Sharifullin, and Marat R. Sitdikov. "Mathematical modeling heat and mass transfer in a vertical hydraulic fracture crack during inflation and cleaning*." Tyumen State University Herald. Physical and Mathematical Modeling. Oil, Gas, Energy 6, no. 2 (2020): 41–62. http://dx.doi.org/10.21684/2411-7978-2020-6-2-41-62.

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When designing hydraulic fracturing for high-temperature formations, it is important to know the temperature change in the fracture during the injection of fracturing fluid. The temperature profile in the hydraulic fracture is necessary to calculate the optimal composition of the fracturing fluid, which necessarily includes a crosslinker (crosslinker) and a breaker (breaker), the concentration of which is calculated by the temperature at the end of the crack. Currently, this concentration is calculated based on the maximum temperature of the formation, which can lead to a decrease in the efficiency of hydraulic fracturing, since a breaker will not completely destroy the crosslinked gel. Therefore, when a well is brought into operation after the stimulation, proppant removal may occur, reducing the effectiveness of stimulation to zero. In this regard, the optimization of the decision-making process in the design of hydraulic fracturing in terrigenous and carbonate reservoirs by calculating the optimal parameters of process fluids based on predicting heat and mass transfer processes occurring during processing is a very urgent task. A tool has been developed to improve the design efficiency of hydraulic fracturing based on mathematical modeling of temperature fields in a hydraulic fracture during its development and during the period of technological sludge. A mathematical model that describes the temperature dynamics in a hydraulic fracture taking into account fluid leakage into the formation represents the evolutionary equation of convective heat transfer with a source, which is defined as the density of the heat flux from the formation. To check the adequacy of the model of temperature dynamics in a hydraulic fracture, a model of temperature recovery in a fracture is presented with the subsequent adaptation of simulation results to actual data. Developed mathematical models can be used in hydraulic fracturing simulators.
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Shen, Feng, Zhou Wu, Nan Wang, and Yong Ming Li. "The Prediction of Wellhead Pressure of Hydraulic Fracturing." Applied Mechanics and Materials 405-408 (September 2013): 3323–27. http://dx.doi.org/10.4028/www.scientific.net/amm.405-408.3323.

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The accurate prediction of wellhead pressure in process of hydraulic fracturing is a keypoint to guide the design and construction of the fracturing, and does help in choosing appropriate wellhead equipment and pipeline. This paper calculates the formation breakdown pressure by using a self-made formation stress calculation software, analyzes perforation friction and near-wellbore friction on the basis of Michael theory, eatablishes a model of wellbore friction through Darcy-Weisbach equation and the momentum interaction theory of two-phase flow, and according to the composition of wellhead pressure, makes calculation software which can also analyze the influencing factor of wellbore friction, such as delivery rate, pipe diameter, fracturing fluid density and proppant size. Finally, case analysis verifies the accuracy of the computing method.
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Eyre, Thomas S., David W. Eaton, Dmitry I. Garagash, et al. "The role of aseismic slip in hydraulic fracturing–induced seismicity." Science Advances 5, no. 8 (2019): eaav7172. http://dx.doi.org/10.1126/sciadv.aav7172.

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Models for hydraulic fracturing–induced earthquakes in shales typically ascribe fault activation to elevated pore pressure or increased shear stress; however, these mechanisms are incompatible with experiments and rate-state frictional models, which predict stable sliding (aseismic slip) on faults that penetrate rocks with high clay or total organic carbon. Recent studies further indicate that the earthquakes tend to nucleate over relatively short injection time scales and sufficiently far from the injection zone that triggering by either poroelastic stress changes or pore pressure diffusion is unlikely. Here, we invoke an alternative model based on recent laboratory and in situ experiments, wherein distal, unstable regions of a fault are progressively loaded by aseismic slip on proximal, stable regions stimulated by hydraulic fracturing. This model predicts that dynamic rupture initiates when the creep front impinges on a fault region where rock composition favors dynamic and slip rate weakening behavior.
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Carpenter, Chris. "Diagnostic Fracture Injection Test Analysis Method Addresses Layered Rocks." Journal of Petroleum Technology 73, no. 02 (2021): 54–55. http://dx.doi.org/10.2118/0221-0054-jpt.

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This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 199690, “Diagnostic Fracture Injection Test Analysis and Interpretation in Layered Rocks,” by Shuang Zheng, SPE, Ripudaman Manchanda, SPE, and HanYi Wang, The University of Texas at Austin, et al., prepared for the 2020 SPE Hydraulic Fracturing Technology Conference and Exhibition, The Woodlands, Texas, 4-6 February. The paper has not been peer reviewed. Formation-property estimations based on diagnostic fracture injection tests (DFITs) typically are based on analysis of pressure data assuming the closure of simple planar fractures in homogeneous reservoirs. These interpretations are incorrect when dealing with complex reservoir environments such as layered reservoirs with different properties and stresses. The complete paper investigates the effect of such complex environments on DFIT interpretation and presents a systematic method to analyze the data. Model Description A fully integrated hydraulic fracturing and reservoir simulator is used in this paper to simulate a DFIT. This simulator has been developed for designing and evaluating pad-scale fracturing treatments. It was then extended from a single-phase flow model to a multiphase black-oil-flow model and from a single-well fracturing simulator to an integrated fracturing and reservoir simulator. An energy-balance model was incorporated into the simulator to consider temperature changes. The fully implicit geomechanical hydraulic fracturing simulator was also extended to an integrated equation-of-state-based compositional fracturing and reservoir simulator in recent work. This simulator, which has been used in the literature and is discussed in detail in the complete paper, couples the reservoir fracture/wellbore system and has the capability to simulate the life cycle of wells: hydraulic fracturing, shut-in, flowback, primary production, and improved oil recovery. Base Case In the base case, a small amount of fluid is injected into the wellbore and the well is shut in for 10 days to mimic a DFIT job. The simulation domain is 400×400 m2 in the horizontal plane and 200 m in the height direction. The perforation clusters are placed in the middle of the domain. The bottomhole pressure vs. time is computed and plotted in this simulation. The simulation involves propagation of a single vertical fracture from a horizontal wellbore drilled in a formation with layered stress heterogeneity. The fracture maintains the largest width in the middle low-stress region, and the two low-stress regions below and above the middle low-stress region also have a large width compared with the fracture-tip regions and the high-stress regions. During fracture closure, fracture width decreases; however, the fracture width in the low-stress region is always higher than in the high-stress region. Results and Discussion The authors applied the numerical DFIT model to study the effect of different layer properties on DFIT signature and its interpretation. The simulation results indicate that most of the layer proper-ties have a major effect on DFIT signature and interpretation.
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Wang, Junjian, and Sheik S. Rahman. "Investigation of Water Leakoff Considering the Component Variation and Gas Entrapment in Shale During Hydraulic-Fracturing Stimulation." SPE Reservoir Evaluation & Engineering 19, no. 03 (2016): 511–19. http://dx.doi.org/10.2118/174392-pa.

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Summary The water leakoff into the shale matrix during the hydraulic-fracture treatment has been a critical issue in determining fracture geometry. Furthermore, water leakoff also affects mechanical properties of the surrounding rock matrix which, in turn, affects fracture propagation. Conventional approaches for the prediction of leakoff were inadequate because several important phenomena are ignored. In this paper, several effects on water leakoff into shale matrix during shale-gas reservoir stimulation are considered. A simplified structure is used to depict the complex pore network in shale. Different interactive forces involved in water displacement considering the osmotic and capillary effects are taken into account in the mathematical formulation of the model. The proposed numerical model is used to study the water leakoff and the consequent pressure increase caused by gas entrapment. The potential influence of the increase in pore pressure on the generation of microfractures is also discussed. The simulation results show reasonable agreement with the previous studies, and indicate that the water leakoff greatly depends on composition and structure of shale matrix. Clay minerals, for example, are naturally prone to water invasion, and draw water faster than hydrophilic minerals and organic matter because of the osmotic effect. Furthermore, the invaded water significantly increases the pore pressure within the shale matrix because of gas entrapment, which leads to a strong nonlinear relationship between leakoff and the square root of time. An increase in pore pressure also results in a decrease in effective stress that leads to the generation of tension-induced microfractures in shale matrix. This study emphasizes the significance of osmotic and capillary effects as well as gas entrapment on hydraulic-fracturing treatment of shale-gas reservoirs. Moreover, the new leakoff model can be applied to assist the investigation of fracture-propagation behavior in a shale-gas reservoir.
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Kishida, Kiyoshi, Shogo Izawa, Sho Ogata, and Hideaki Yasuhara. "Development of rock fracturing model considering mineral composition and distribution and its application to coupled Thermal-Hydraulic-Mechanical-Chemical (THMC) simulator." Japanese Geotechnical Society Special Publication 8, no. 3 (2020): 76–81. http://dx.doi.org/10.3208/jgssp.v08.j45.

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Cahalan, Mark, David Moskal, Cimon Song, and Jianhan Wu. "Optimization of reverse osmosis flowback water treatment using halotolerant microbes naturally enriched in fractured shales." University of Ottawa Science Undergraduate Research Journal 1 (August 23, 2018): 60. http://dx.doi.org/10.18192/osurj.v1i1.3720.

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Flowback water recovered after hydraulic fracturing operations poses a serious environmental concern due to the sheer quantity produced and its toxic chemical composition. Traditional methods of wastewater treatment cannot be used for flowback water treatment due to its high concentration of non-biodegradable dissolved solids. Consequently, alternative technology has been developed to address this problem. Reverse osmosis (RO) treatment is one such example. However, guar gum gelling agents found in flowback water impede membrane permeability and water flux rate of RO, consequently decreasing the efficiency and practicality of this desirable, environment-friendly technology. Previously, a biological solution using activated sludge to degrade guar gum prior to RO treatment was attempted with limited success due to the inhibitory effects of hypersalinity (characterized by high total dissolved solids content) on microbial activity. To solve this problem, several recently discovered strains of bacteria and archaea found to be naturally enriched in fractured shales may be utilized through genetic modification to degrade guar gum under hypersaline conditions. These microbes are naturally halotolerant and thrive under hypersaline conditions, making them prime targets for genetic modification targeting various chemical additives in flowback water. Here, we provide a proof of concept model using these microbes to selectively target guar gum degradation to improve the efficiency of RO treatment.
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Fung, Larry S., and Shouhong Du. "Parallel-Simulator Framework for Multipermeability Modeling With Discrete Fractures for Unconventional and Tight Gas Reservoirs." SPE Journal 21, no. 04 (2016): 1370–85. http://dx.doi.org/10.2118/179728-pa.

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Summary Economic gas rate from ultralow-permeability shale reservoirs requires the creation of a complex fracture network in a large volume known as the stimulated reservoir volume (SRV). The fracture network connects a large surface area of the reservoir to the well. It is created by injecting low-viscosity fracturing fluid (slickwater) at very high rates in multiple stages along the horizontal wellbore. Numerical simulation is used to evaluate the stimulation designs and completion strategy. Microseismic (MS) -survey fracture mapping can provide a measurement of the overall SRV and an estimate of the fracture patterns. Special core analyses provide estimates of shale-matrix permeability. The extent of the fracture network indicates that there is insufficient proppant volume, and many stimulated fractures may be only partially propped or may be unpropped. Thus, fracture conductivity will vary spatially caused by uneven proppant distribution and temporally caused by stress sensitivity upon pressure decline during production. Because of the vast contrast in conductivity between stimulated/hydraulic fractures (darcy-ft) and shale matrix (nd-ft), the transient response in matrix/fracture flow cannot be captured accurately if the stimulated fractures are approximated with large dual-continuum (DC) gridblocks. The gridding requirement to achieve an accurate solution in fractured shale reservoirs is investigated and discussed. In this work, the stimulated and hydraulic fractures are discretized explicitly to form a discrete fracture network (DFN). This paper discusses the mathematical framework and parallel numerical methods for simulating unconventional reservoirs. The simulation methods incorporate known mechanisms and processes for shale, which include gas sorption in organic matter; combined Knudsen diffusion and viscous flow in nanopores; stress-sensitive fracture permeability; and velocity-dependent flow in the high-conductivity hydraulic fractures. The simulation system is based on a general finite-volume method that includes a multiconnected multicontinuum (MC) representation of the pore system with either a compositional or a black-oil fluid description. The MC model is used to represent the storage and intercommunication among the various porosities in shale (organic matter, inorganic matter, fine unstimulated natural fractures). Unconventional simulation involves many more nonlinearities, and the extreme contrast in permeabilities will make the problems harder to solve. We discuss numerical implementation of the methods for modeling the mechanisms and processes in fractured shale. In addition, we discuss the MC formulation, the discretization method, the unstructured parallel domain-decomposition method, and the solution method for the simulation system. Finally, we explain our efforts in numerical validation of the system with fine-grid single-porosity simulation. We show numerical examples to demonstrate the applications of the simulator and to study the transient flow behavior in shale reservoirs. The effects of the various mechanisms for gas production are also evaluated.
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Tesis sobre el tema "Compositional hydraulic fracturing model"

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Morgan, William Edmund. "A fully implicit stochastic model for hydraulic fracturing based on the discontinuous deformation analysis." Diss., Georgia Institute of Technology, 2014. http://hdl.handle.net/1853/53073.

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In recent years, hydraulic fracturing has led to a dramatic increase in the worldwide production of natural gas. In a typical hydraulic fracturing treatment, millions of gallons of water, sand and chemicals are injected into a reservoir to generate fractures in the reservoir that serve as pathways for fluid flow. Recent research has shown that both the effectiveness of fracturing treatments and the productivity of fractured reservoirs can be heavily influenced by the presence of pre-existing natural fracture networks. This work presents a fully implicit hydro-mechanical algorithm for modeling hydraulic fracturing in complex fracture networks using the two-dimensional discontinuous deformation analysis (DDA). Building upon previous studies coupling the DDA to fracture network flow, this work emphasizes various improvements made to stabilize the existing algorithms and facilitate their convergence. Additional emphasis is placed on validation of the model and on extending the model to the stochastic characterization of hydraulic fracturing in naturally fractured systems. To validate the coupled algorithm, the model was tested against two analytical solutions for hydraulic fracturing, one for the growth of a fixed-length fracture subject to constant fluid pressure, and the other for the growth of a viscosity-storage dominated fracture subject to a constant rate of fluid injection. Additionally, the model was used to reproduce the results of a hydraulic fracturing experiment performed using high-viscosity fracturing fluid in a homogeneous medium. Very good agreement was displayed in all cases, suggesting that the algorithm is suitable for simulating hydraulic fracturing in homogeneous media. Next, this work explores the relationship between the maximum tensile stress and Mohr-Coulomb fracture criteria used in the DDA and the critical stress intensity factor criteria from linear elastic fracture mechanics (LEFM). The relationship between the criteria is derived, and the ability of the model to capture the relationship is examined for both Mode I and Mode II fracturing. The model was then used to simulate the LEFM solution for a toughness-storage dominated bi-wing hydraulic fracture. Good agreement was found between the numerical and theoretical results, suggesting that the simpler maximum tensile stress criteria can serve as an acceptable substitute for the more rigorous LEFM criteria in studies of hydraulic fracturing. Finally, this work presents a method for modeling hydraulic fracturing in reservoirs characterized by pre-existing fracture networks. The ability of the algorithm to correctly model the interaction mechanism of intersecting fractures is demonstrated through comparison with experimental results, and the method is extended to the stochastic analysis of hydraulic fracturing in probabilistically characterized reservoirs. Ultimately, the method is applied to a case study of hydraulic fracturing in the Marcellus Shale, and the sensitivity of fracture propagation to variations in rock and fluid parameters is analyzed.
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Papachristos, Efthymios. "A 3D hydro-mechanical discrete element model for hydraulic fracturing in naturally fractured rock." Thesis, Université Grenoble Alpes (ComUE), 2017. http://www.theses.fr/2017GREAI016/document.

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La fracturation hydraulique est au cœur d'un certain nombre de phénomènes naturels et induits et est cruciale pour un développement durable de la production de ressources énergétiques. Compte tenu de son rôle crucial, ce phénomène a été pris en compte au cours des trois dernières décennies par le monde académique. Néanmoins, un certain nombre d'aspects très importants de ce processus ont été systématiquement négligés par la communauté. Deux des plus remarquables sont l'incapacité de la grande majorité des modèles existants à aborder la propagation des fractures hydrauliques dans les massifs rocheux fracturés où l'injection de fluide peut à la fois conduire à la fracturation de la roche intacte et à la réactivation de fractures préexistantes. Un autre aspect essentiel de ce processus est qu'il est intrinsèquement tridimensionnel, ce qui est souvent négligé par les modèles actuellement disponibles. Pour aborder ce problème essentiel, un modèle hydro-mécanique couplé basé sur la méthode des éléments discrets a été développé. La masse rocheuse est ici représentée par un ensemble d'éléments discrets interagissant à travers des lois de contact cohésifs qui peuvent se casser pour former des fissures à l'intérieur du milieu simulé. Ces fissures peuvent se coalescer pour former des fractures. Une méthode de volume fini est utilisée pour simuler l'écoulement de fluide entre les éléments discrets. L'écoulement est calculé en fonction de la déformation de l'espace poreux dans le milieu intact et de l'ouverture des fissures dans les fractures. De plus, les fractures naturelles sont modélisées explicitement de sorte qu'elles peuvent présentées des comportements mécanique et hydraulique différents de ceux de la matrice rocheuse intacte. La simulation des processus de fracturation hydraulique dans un milieu initialement intact en considérant plusieurs points d'injection plus ou moins espacés a permis de mettre en évidence l'évolution spatio-temporelle des fractures hydrauliques et de quantifier l'impact des différentes stratégies d'injection sur des indices représentatifs du volume fracturé, de l'intensité et de la densité des fractures ou encore sur la pression de fluide au niveau du puits. De plus, l'injection dans une fente de perforation non alignée sur le plan de contrainte minimum a génère des fractures hydrauliques non planaires percolantes si la connectivité est faible, ce qui peut être gênant pour la mise en place du proppant. En outre, des interactions fortes prennent place entre des fractures hydrauliques étroitement espacées ont été mises en évidence grâce au le suivi de la orientation de contrainte principale locale et ont révélé l'importance des effets d'ombre de contrainte. Des solutions sont proposées pour optimiser les traitements multiples à partir d'un puits de forage non parfaitement aligné. Enfin, l'interaction entre une seule fracture hydraulique et une seule fracture naturelle de propriétés et d'orientations variables a été étudiée à l'aide du modèle proposé. L'évolution de la fracture hydraulique et la réponse globale de l'échantillon ont été enregistrées d'une manière comparable aux données expérimentales existantes pour établir un pont entre les résultats expérimentaux et numériques. Les fractures naturelles persistantes semblent être des barrières pour la fracture hydraulique si leur conductance est élevée par apport a celle de la matrice ou si leur raideur est faible par rapport a la rigidité du milieu environnant. D'autre part, une faible rigidité dans les discontinuités non persistantes pourrait provoquer une bifurcation de la fracture hydraulique principale. De plus, des angles d'approche élevés et des contraintes différentielles fortes semblent favoriser le croisement de la fracture naturelle alors que des angles faibles engendrent plutôt un glissement ou une dilatation par cisaillement de la partie du plan qui n'est pas affectée par la perturbation de la contrainte<br>Hydraulic fracturing is at the core of a number of naturally occurring and induced phenomena and crucial for a sustainable development of energy resource production. Given its crucial role this process has been given increasing attention in the last three decades from the academic world. Nonetheless a number of very significant aspects of this process have been systematically overlooked by the community. Two of the most notable ones are the inability of the vast majority of existing models to tackle at once the propagation of hydraulic fractures in realistic, fractured rocks-masses where hydraulic fracturing is a competing dipole mechanism between fracturing of the intact rock and re-activation of exiting fracture networks. Another essential aspect of this process is that it is intrinsically three-dimensional which is neglected by most models. To tackle this vital problem taking into account these pivotal aspects, a fully coupled hydro-mechanical model based on the discrete element method has been developed. The rock mass is here represented by a set of discrete elements interacting through elastic-brittle bonds that can break to form cracks inside the simulated medium. Theses cracks can coalesce to form fractures. A finite volume scheme is used to simulate the fluid flow in between these discrete elements. The flow is computed as a function of the pore space deformation in the intact medium and of the cracks' aperture in the fractures. Furthermore, the natural fractures are modelled explicitly and present mechanical and hydraulic properties different from the rock matrix. Employing this model in an intact numerical specimen, single fluid injection and multiple closely spaced sequential injections, enabled the description the full spatio-temporal evolution of HF propagation and its impact on quantitative indexes used in description of hydraulic fracturing treatments, such as fractured volume, fracture intensity and down-the-hole pressure for different control parameters and in-situ stress-fields. Moreover, injections from perforation slots which are not well aligned to the minimum stress plane showed possible creation of percolating non-planar hydraulic fractures of low connectivity, which can be troublesome for proppant placement. Also, strong interactions between closely spaced HF were highlighted by tracking the local principal stress rotation around the injection zones, emphasizing the importance of stress shadow effects. Optimization solutions are proposed for multiple treatments from a non-perfectly aligned wellbore. Finally, interaction between a single hydraulic fracture and a single natural fracture of varying properties and orientations was studied using the proposed model. The evolution of the hydraulic fracture and the global response of the specimen were recorded in a way comparable to existing experimental data to bridge the experimental and numerical findings. Persistent natural fractures appeared to be barriers for the hydraulic fracture if their conductance is high compared to the matrix conductivity or if their stiffness is significantly low compared to the rock matrix rigidity. Low stiffness in non-persistent defects might also cause a bifurcation of the main hydraulic fracture due to the local stress field perturbation around the defect and ahead of the hydraulic fracture tip. Furthermore, high approach angles and differential stresses seemed to favour crossing of the natural fracture while low angles enable shear slippage or dilation on the part of the plane which is not affected by the local stress perturbation
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Wong, John Kam-wing. "Three-dimensional multi-scale hydraulic fracturing simulation in heterogeneous material using Dual Lattice Model." Thesis, University of Cambridge, 2018. https://www.repository.cam.ac.uk/handle/1810/270542.

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Hydraulic fracturing is a multi-physics multi-scale problem related to natural processes such as the formation of dikes. It also has wide engineering applications such as extraction of unconventional resources, enhanced geothermal energy and carbon capture and storage. Current simulators are highly simplified because of the assumption of homogeneous reservoir. Unconventional reservoirs are heterogeneous owing to the presence of natural fracture network. Because of high computational effort, three-dimensional multi-scale simulations are uncommon, in particular, modelling material as a heterogeneous medium. Lattice Element Method (LEM) is therefore proposed for multi-scale simulation of heterogeneous material. In LEM, material is discretised into cells and their interactions are modelled by lattices, hence a three-dimensional model is simplified to a network of one-dimensional lattice. Normal, shear and rotational springs are used to define the constitutive laws of a lattice. LEM enables desktop computers for simulation of a lattice model that consists of millions of lattices. From simulations, normal springs govern the macroscopic bulk deformation while shear springs govern the macroscopic distortion. There is fluctuation of stresses even under uniform loading which is one of the characteristics of a lattice model. The magnitude increases with the stiffness ratio of shear spring to normal spring. Fracturing process can be modelled by LEM by introducing a microscopic tensile strength and a microscopic shear strength to the lattice properties. The strength parameters can be related to fracture toughness with the length scales of cells. From simulations, the relationships between model parameters and macroscopic parameters that are measurable in experiments are identified. From the simulations of uni-axial tension tests, both the spring stiffness ratio and the applied heterogeneity govern the fracturing process. The heterogeneity increases the ductility at the expense of the reduction on the macroscopic strengths. Different stages of fracturing are identified which are characterised by the model heterogeneity. Heterogeneous models go through the stages of the spatially distributed microscrack formation, the growth of multiple fracture clusters to the dominant fracture propagation. For homogeneous models, one of the microcracks rapidly propagates and becomes a dominant fracture with the absence of intermediate stages. From the uni-axial compression test simulations, the peak compressive stress is reached at the onset of the microscopic shear crack formation. Ductility is governed by the stiffness reduction ratio of a lattice in closed fractured stage to its unfractured stage. A novel Dual Lattice Model (DLM) is proposed for hydraulic fracture simulation by coupling a solid lattice model with a fluid lattice model. From DLM simulations of hydraulic fracturing of the classical penny shape crack problem under hydrostatic condition, the heterogeneities from both the fracture asperity and the applied heterogeneity increase the apparent fracture toughness. A semi-analytical solution is derived to consider the effect of fluid viscosity in the elastic deformation regime. Two asymptotes are identified that gives steep pressure gradients near the injection point and near the fracture tip which are also identified in the DLM simulations. Simulations also show three evolving regimes on energy dissipation/transfer mechanisms: the viscosity dominant, the elastic deformation dominant and the mixture of elastic deformation and toughness.
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Van, Der Merwe Carel Wagener. "A peridynamic model for sleeved hydraulic fracture." Thesis, Stellenbosch : Stellenbosch University, 2014. http://hdl.handle.net/10019.1/95993.

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Thesis (MEng)--Stellenbosch University, 2014.<br>ENGLISH ABSTRACT: Current numerical methods in the eld of hydraulic fracturing are based mainly on continuum methods, such as the Finite Element Method (FEM) and the Boundary Element Method (BEM). These methods are governed by Linear Elastic Fracture Mechanics (LEFM) criteria, which su er from the inherent aw of a non-physical stress representation at the fracture tip. In response to this, a non-local method is proposed, namely the peridynamic theory, to model sleeved hydraulic fracture. A 2D implicit quasi-static ordinary state based peridynamic formulation is implemented on various benchmark problems, to verify the ability to capture constitutive behaviour in a linear elastic solid, as well as, the quanti cation of adverse e ects on the accuracy of the displacement solution, due to the nature of the non-local theory. Benchmark tests consist of a plate in tension, where convergence to the classical displacement solution, non-uniform re nement and varying cell sizes are tested, as well as, a thick walled cylinder with internal pressure, where three di erent loading techniques are tested. The most accurate loading technique is applied to the sleeved fracture model, in order to simulate fracture initiation and propagation. This model is then veri ed and validated by using the Rummel & Winter hydraulic fracturing model and experimental results, respectively. Displacement error minimisation methods are implemented and as a result, the displacement solutions for a plate in tension converges to the analytical solution, while the thick walled cylinder solutions su er from inaccuracies due to an applied load on an irregularly discretized region. The fracture initiation test captures the fracture tip behaviour of the Rummel & Winter model and the fracture propagation test show good correlation with experimental results. This research shows that the peridynamic approach to sleeved hydraulic fracture can yield a realistic representation of fracture initiation and propagation, however, further research is needed in the area of a pressure load application on a solid using the peridynamic approach.<br>AFRIKAANSE OPSOMMING: Huidige numeriese metodes in die veld van hidrouliese breking is hoofsaaklik gebaseer op kontinuum metodes, soos die Eindige Element Metode (EEM) en die Rand Element Metode (REM). Hierdie metodes word beheer deur Linie^ere Elastiese Breukmeganika (LEB) kriteria, wat ly aan die inherente gebrek van 'n nie- siese voorstelling van die spanning by die fraktuur punt. Om hierdie probleme aan te spreek, word 'n nie-lokale metode voorgestel, naamlik die peridinamiese teorie, om gehulsde hidrouliese breking te modelleer. 'n 2D implisiete kwasi-statiese ordin^ere toestand gebaseerde peridinamika formulering word ge mplimenteer op verskeie norm probleme, om te veri eer of dit oor die vermo e beskik om die konstitutiewe gedrag van 'n linie^ere elastiese soliede materiaal te modeleer, asook die kwanti sering van nadelige e ekte op die verplasings oplossing as gevolg van die natuur van die nie-lokale teorie. Normtoetse bestaan uit 'n plaat in trek spanning, waar konvergensie na die klassieke verplasings oplossing, nie-uniforme verfyning en vari^eerende sel groottes getoets word, asook 'n dikwandige silinder onder interne druk, waar drie verskillende belasting aanwendingstegnieke getoets word. Die mees akkurate belasting aanwendingstegniek word dan gebruik in die gehulsde hidrouliese breking model, om fraktuur aanvangs en uitbreiding na te boots. Die model word dan geveri- eer deur die Rummel & Winter hidrouliese breking model en eksperimentele resultate, onderskeidelik. Fout minimering metodes word toegepas en as 'n resultaat, konvergeer die verplasing oplossing vir die plaat na die analitiese oplossing, terwyl die oplossing van die dikwandige silinder onakuraathede toon as gevolg van 'n toegepaste belasting op 'n onre elmatig gediskretiseerde gebied. Die modellering van die fraktuur inisi ering by die fraktuur punt, stem goed ooreen met die Rummel en Winter voorspelling en die fraktuur uitbreiding stem goed ooreen met eksperimentele resultate. Hierdie navorsing toon dat die peridinamiese benadering tot gehulsde hidrouliese breking wel die fraktuur inisi ering en uitbreiding realisties kan modelleer, maar nog navorsing word wel benodig in die area waar 'n druk belasting op 'n peridinamiese soliede model toegepas word.
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Shrestha, Aashish. "Modeling Impact of Hydraulic Fracturing and Climate Change on Stream Low Flows: A Case Study of Muskingum Watershed in Eastern Ohio." Youngstown State University / OhioLINK, 2014. http://rave.ohiolink.edu/etdc/view?acc_num=ysu1420797464.

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Luo, Chenyi [Verfasser], and Wolfgang [Akademischer Betreuer] Ehlers. "A phase-field model embedded in the theory of porous media with application to hydraulic fracturing / Chenyi Luo ; Betreuer: Wolfgang Ehlers." Stuttgart : Universitätsbibliothek der Universität Stuttgart, 2019. http://d-nb.info/1184884099/34.

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Nadeem, Muhammad. "Reservoir screening criteria for deep slurry injection." Thesis, University of Waterloo, 2005. http://hdl.handle.net/10012/1254.

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Deep slurry injection is a process of solid waste disposal that involves grinding the solid waste to a relatively fine-grained consistency, mixing the ground waste with water and/or other liquids to form slurry, and disposing of the slurry by pumping it down a well at a high enough pressure that fractures are created within the target formation. This thesis describes the site assessment criteria involved in selecting a suitable target reservoir for deep slurry injection. The main goals of this study are the follows: <ul> <li>Identify the geological parameters important for a prospective injection site</li> <li>Recognize the role of each parameter</li> <li>Determine the relationships among different parameters</li> <li>Design and develop a model which can assemble all the parameters into a semi-quantitative evaluation process that could allow site ranking and elimination of sites that are not suitable</li> <li>Evaluate the model against several real slurry injection cases and several prospective cases where slurry injection may take place in future</li> </ul> The quantitative and qualitative parameters that are recognized as important for making a decision regarding a target reservoir for deep slurry injection operations are permeability, porosity, depth, areal extent, thickness, mechanical strength, and compressibility of a reservoir; thickness and flow properties of the cap rock; geographical distance between an injection well and a waste source or collection centre; and, regional and detailed structural and tectonic setup of an area. Additional factors affecting the security level of a site include the details of the lithostratigraphic column overlying the target reservoir and the presence of overlying fracture blunting horizons. Each parameter is discussed in detail to determine its role in site assessment and also its relationship with other parameters. A geological assessment model is developed and is divided into two components; a decision tree and a numerical calculation system. The decision tree deals with the most critical parameters, those that render a site unsuitable or suitable, but of unspecified quality. The numerical calculation gives a score to a prospective injection site based on the rank numbers and weighting factors for the various parameters. The score for a particular site shows its favourability for the injection operation, and allows a direct comparison with other available sites. Three categories have been defined for this purpose, i. e. average, below average, and above average. A score range of 85 to 99 of 125 places a site in the ?average? category; a site will be unsuitable for injection if it belongs to the ?below average? category, i. e. if the total score is less than 85, and the best sites will generally have scores that are in the ?above average? category, with a score of 100 or higher. One may assume that for sites that fall in the ?average? category there will have to be more detailed tests and assessments. The geological assessment model is evaluated using original geological data from North America and Indonesia for sites that already have undergone deep slurry injection operations and also for some possible prospective sites. The results obtained from the model are satisfactory as they are in agreement with the empirical observations. Areas for future work consist of the writing of a computer program for the geological model, and further evaluation of the model using original data from more areas representing more diverse geology from around the world.
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Bouteca, Maurice. "Fracturation hydraulique calcul de propagation d'une fracture induite dans un massif rocheux /." Grenoble 2 : ANRT, 1987. http://catalogue.bnf.fr/ark:/12148/cb37603363t.

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Tanne, Erwan. "Variational phase-field models from brittle to ductile fracture : nucleation and propagation." Thesis, Université Paris-Saclay (ComUE), 2017. http://www.theses.fr/2017SACLX088/document.

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Les simulations numériques des fissures fragiles par les modèles d’endommagement à gradient deviennent main- tenant très répandues. Les résultats théoriques et numériques montrent que dans le cadre de l’existence d’une pre-fissure la propagation suit le critère de Griffith. Alors que pour le problème à une dimension la nucléation de la fissure se fait à la contrainte critique, cette dernière propriété dimensionne le paramètre de longueur interne.Dans ce travail, on s’attarde sur le phénomène de nucléation de fissures pour les géométries communément rencontrées et qui ne présentent pas de solutions analytiques. On montre que pour une entaille en U- et V- l’initiation de la fissure varie continument entre la solution prédite par la contrainte critique et celle par la ténacité du matériau. Une série de vérifications et de validations sur diffèrent matériaux est réalisée pour les deux géométries considérées. On s’intéresse ensuite à un défaut elliptique dans un domaine infini ou très élancé pour illustrer la capacité du modèle à prendre en compte les effets d’échelles des matériaux et des structures.Dans un deuxième temps, ce modèle est étendu à la fracturation hydraulique. Une première phase de vérification du modèle est effectuée en stimulant une pré-fissure seule par l’injection d’une quantité donnée de fluide. Ensuite on étudie la simulation d’un réseau parallèle de fissures. Les résultats obtenus montrent qu’il a qu’une seule fissure qui se propage et que ce type de configuration minimise mieux l’énergie la propagation d’un réseau de fractures. Le dernier exemple se concentre sur la stabilité des fissures dans le cadre d’une expérience d’éclatement à pression imposée pour l’industrie pétrolière. Cette expérience d’éclatement de la roche est réalisée en laboratoire afin de simuler les conditions de confinement retrouvées lors des forages.La dernière partie de ce travail se concentre sur la rupture ductile en couplant le modèle à champ de phase avec les modèles de plasticité parfaite. Grâce à l’approche variationnelle du problème on décrit l’implantation numérique retenue pour le calcul parallèle. Les simulations réalisées montrent que pour une géométrie légèrement entaillée la phénoménologie des fissures ductiles comme par exemple la nucléation et la propagation sont en concordances avec ceux reportées dans la littérature<br>Phase-field models, sometimes referred to as gradient damage, are widely used methods for the numerical simulation of crack propagation in brittle materials. Theoretical results and numerical evidences show that they can predict the propagation of a pre-existing crack according to Griffith’s criterion. For a one- dimensional problem, it has been shown that they can predict nucleation upon a critical stress, provided that the regularization parameter is identified with the material’s internal characteristic length.In this work, we draw on numerical simulations to study crack nucleation in commonly encountered geometries for which closed-form solutions are not available. We use U- and V-notches to show that the nucleation load varies smoothly from the one predicted by a strength criterion to the one of a toughness criterion when the strength of the stress concentration or singularity varies. We present validation and verification of numerical simulations for both types of geometries. We consider the problem of an elliptic cavity in an infinite or elongated domain to show that variational phase field models properly account for structural and material size effects.In a second movement, this model is extended to hydraulic fracturing. We present a validation of the model by simulating a single fracture in a large domain subject to a control amount of fluid. Then we study an infinite network of pressurized parallel cracks. Results show that the stimulation of a single fracture is the best energy minimizer compared to multi-fracking case. The last example focuses on fracturing stability regimes using linear elastic fracture mechanics for pressure driven fractures in an experimental geometry used in petroleum industry which replicates a situation encountered downhole with a borehole called burst experiment.The last part of this work focuses on ductile fracture by coupling phase-field models with perfect plasticity. Based on the variational structure of the problem we give a numerical implementation of the coupled model for parallel computing. Simulation results of a mild notch specimens are in agreement with the phenomenology of ductile fracture such that nucleation and propagation commonly reported in the literature
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Friehauf, Kyle Eugene. "Simulation and design of energized hydraulic fractures." 2009. http://hdl.handle.net/2152/6644.

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Hydraulic fracturing is essential for producing gas and oil at an economic rate from low permeability sands. Most fracturing treatments use water and polymers with a gelling agent as a fracturing fluid. The water is held in the small pore spaces by capillary pressure and is not recovered when drawdown pressures are low. The un-recovered water leaves a water saturated zone around the fracture face that stops the flow of gas into the fracture. This is a particularly acute problem in low permeability formations where capillary pressures are high. Depletion (lower reservoir pressures) causes a limitation on the drawdown pressure that can be applied. A hydraulic fracturing process can be energized by the addition of a compressible, sometimes soluble, gas phase into the treatment fluid. When the well is produced, the energized fluid expands and gas comes out of solution. Energizing the fluid creates high gas saturation in the invaded zone, thereby facilitating gas flowback. A new compositional hydraulic fracturing model has been created (EFRAC). This is the first model to include changes in composition, temperature, and phase behavior of the fluid inside the fracture. An equation of state is used to evaluate the phase behavior of the fluid. These compositional effects are coupled with the fluid rheology, proppant transport, and mechanics of fracture growth to create a general model for fracture creation when energized fluids are used. In addition to the fracture propagation model, we have also introduced another new model for hydraulically fractured well productivity. This is the first and only model that takes into account both finite fracture conductivity and damage in the invaded zone in a simple analytical way. EFRAC was successfully used to simulate several fracture treatments in a gas field in South Texas. Based on production estimates, energized fluids may be required when drawdown pressures are smaller than the capillary forces in the formation. For this field, the minimum CO2 gas quality (volume % of gas) recommended is 30% for moderate differences between fracture and reservoir pressures (2900 psi reservoir, 5300 psi fracture). The minimum quality is reduced to 20% when the difference between pressures is larger, resulting in additional gas expansion in the invaded zone. Inlet fluid temperature, flowrate, and base viscosity did not have a large impact on fracture production. Finally, every stage of the fracturing treatment should be energized with a gas component to ensure high gas saturation in the invaded zone. A second, more general, sensitivity study was conducted. Simulations show that CO2 outperforms N2 as a fluid component because it has higher solubility in water at fracturing temperatures and pressures. In fact, all gas components with higher solubility in water will increase the fluid’s ability to reduce damage in the invaded zone. Adding methanol to the fracturing solution can increase the solubility of CO2. N2 should only be used if the gas leaks-off either during the creation of the fracture or during closure, resulting in gas going into the invaded zone. Experimental data is needed to determine if the gas phase leaks-off during the creation of the fracture. Simulations show that the bubbles in a fluid traveling across the face of a porous medium are not likely to attach to the surface of the rock, the filter cake, or penetrate far into the porous medium. In summary, this research has created the first compositional fracturing simulator, a useful tool to aid in energized fracture design. We have made several important and original conclusions about the best practices when using energized fluids in tight gas sands. The models and tools presented here may be used in the future to predict behavior of any multi-phase or multi-component fracturing fluid system.<br>text
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Capítulos de libros sobre el tema "Compositional hydraulic fracturing model"

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Leontiev, Arkady, and Ekaterina Rubtsova. "Analysis of Crack Formation in Model Specimens During Hydraulic Fracturing in Holes." In Springer Proceedings in Earth and Environmental Sciences. Springer International Publishing, 2019. http://dx.doi.org/10.1007/978-3-030-31970-0_27.

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Xiang-jun, Xie, and Yu Ting. "Application of T-S Fuzzy Model in Candidate-well Selection for Hydraulic Fracturing." In Advances in Intelligent Systems and Computing. Springer Berlin Heidelberg, 2013. http://dx.doi.org/10.1007/978-3-642-38667-1_55.

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Damjanac, B., C. Detournay, P. A. Cundall, and Varu. "Three-Dimensional Numerical Model of Hydraulic Fracturing in Fractured Rock Masses." In Effective and Sustainable Hydraulic Fracturing. InTech, 2013. http://dx.doi.org/10.5772/56313.

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Kresse, Olga, Xiaowei Weng, Dimitry Chuprakov, Romain Prioul, and Charles Cohe. "Effect of Flow Rate and Viscosity on Complex Fracture Development in UFM Model." In Effective and Sustainable Hydraulic Fracturing. InTech, 2013. http://dx.doi.org/10.5772/56406.

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Frash, Luke, Marte Gutierrez, and Jesse Hampto. "Scale Model Simulation of Hydraulic Fracturing for EGS Reservoir Creation Using a Heated True-Triaxial Apparatus." In Effective and Sustainable Hydraulic Fracturing. InTech, 2013. http://dx.doi.org/10.5772/56113.

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Galindo-Torres, S., S. Behraftar, A. Scheuermann, and L. Li. "A micromechanical model for studies of hydraulic fracturing." In Computer Methods and Recent Advances in Geomechanics. CRC Press, 2014. http://dx.doi.org/10.1201/b17435-278.

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"Appendix IV: Solubility of Organic Molecules in Water: A Surface Tension—Cavity Model System (Structure of Water and Gas Hydrates)." In Surface Chemistry and Geochemistry of Hydraulic Fracturing. CRC Press, 2016. http://dx.doi.org/10.1201/9781315372372-14.

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Ben, Y., Y. Wang, and Gen-hua Shi. "Development of a model for simulating hydraulic fracturing with DDA." In Frontiers of Discontinuous Numerical Methods and Practical Simulations in Engineering and Disaster Prevention. CRC Press, 2013. http://dx.doi.org/10.1201/b15791-21.

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"Parameter inverse analysis from hydraulic fracturing using hybrid MSVM-ABC model." In Transit Development in Rock Mechanics. CRC Press, 2014. http://dx.doi.org/10.1201/b17617-61.

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"Chapter 8 Damage model for reservoir with multisets of natural fractures and its application in the simulation of hydraulic fracturing." In Numerical Simulation in Hydraulic Fracturing: Multiphysics Theory and Applications. CRC Press, 2017. http://dx.doi.org/10.1201/9781315206196-9.

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Actas de conferencias sobre el tema "Compositional hydraulic fracturing model"

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Friehauf, Kyle E., Mukul Mani Sharma, and Richard Burl Sullivan. "Application of a New Compositional Model for Hydraulic Fracturing With Energized Fluids: A South Texas Case Study." In SPE Hydraulic Fracturing Technology Conference. Society of Petroleum Engineers, 2009. http://dx.doi.org/10.2118/119265-ms.

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Friehauf, Kyle E., and Mukul Mani Sharma. "A New Compositional Model for Hydraulic Fracturing With Energized Fluids." In SPE Annual Technical Conference and Exhibition. Society of Petroleum Engineers, 2008. http://dx.doi.org/10.2118/115750-ms.

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Gdanski, Rick David, Jim Dean Weaver, and Billy F. Slabaugh. "A New Model for Matching Fracturing Fluid Flowback Composition." In SPE Hydraulic Fracturing Technology Conference. Society of Petroleum Engineers, 2007. http://dx.doi.org/10.2118/106040-ms.

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Ribeiro, Lionel, and Mukul M. Sharma. "A New Three-Dimensional, Compositional, Model for Hydraulic Fracturing with Energized Fluids." In SPE Annual Technical Conference and Exhibition. Society of Petroleum Engineers, 2012. http://dx.doi.org/10.2118/159812-ms.

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Ariaratnam, Samuel T., Richard Stauber, and Bruce Harbin. "Modeling of Annular Pressures in Horizontal Directional Drilling." In 2004 International Pipeline Conference. ASMEDC, 2004. http://dx.doi.org/10.1115/ipc2004-0696.

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Horizontal Directional Drilling (HDD) is an established trenchless construction method for the installation of underground utilities and pipelines. Subsequently, the method is becoming widely accepted as a cost-effective alternative to traditional open-cut construction. However, the occurrence of hydraulic fracturing, resulting in the migration of drilling fluid to the surface has placed the HDD process under scrutiny, especially when being considered for environmentally sensitive projects. Hydraulic fracturing results from an excess buildup of fluidic pressure within the borehole. Models have been developed to predict borehole pressures; however, there is limited information available on the relationship between drilling returns and fluid composition to these pressures. A research program was undertaken to model and determine flow characteristics for drilling returns under a variety of soil conditions and bore penetration rates. Nine soil samples were gathered based on the Unified Soil Classification System (USCS) and their respective rheological properties were obtained for different drilling fluids and target slurry densities. This paper presents, as an example, a comparison and analysis of the predicted borehole pressures of clayey-sand (SC) soil in a large directional drill rig application and provides recommendations for contractors when attempting installations in various geological formations. The pressure effects of pipe eccentricity within a borehole were analyzed using a computer model. The result of this research is a simplified approach for predicting downhole fluid pressures for a wide range of project parameters that can be used as a guide to minimize the occurrence of hydraulic fracturing.
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Vazquez, O., R. Mehta, E. Mackay, S. Linares-Samaniego, M. Jordan, and J. Fidoe. "Post-frac Flowback Water Chemistry Matching in a Shale Development." In SPE International Oilfield Scale Conference and Exhibition. SPE, 2014. http://dx.doi.org/10.2118/spe-169799-ms.

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Abstract Shale developments are normally hydraulic fractured to stimulate the low permeability of the reservoirs, in order to allow fluid to flow to the wellbore. The most common fluid fracture deployed in shale developments is slickwater; which is typically composed volumetrically of approximately 95% water, 4% proppant and 1% other chemicals such as scale inhibitor, surfactant, biocide and corrosion inhibitor. Water management in shale plays accounts for 5% - 15% of total well completion costs. This study investigates the fate of fracturing fluids in shale developments and attempts to understand the effect of fracturing fluid trapped within the reservoir. Approximately 5% - 50% of fracturing fluid pumped is flowed back as the well is put on production. Scale deposition is often experienced within these wells due to the interaction of fracturing fluid lost to the formation reacting with formation brines. It is estimated that the formation of scale within the reservoir, blocks of nano-pores and reduces to some extent the fraction of fracturing fluid returned. The main purpose of this study was to simulate the post-frac flowback composition using a reactive transport model. The model simulates the injection of the fracture fluid, when in contact with the reservoirs minerals, a number of geochemical processes take place and with subsequent production further reactions are possible. The model was used to evaluate the possible causes of the high TDS content in the post-frac water, on one hand dissolution of salts present in the shale or the breaching of deep saline aquifers during fracturing. The value of this paper being to the industry is to increase the understanding of the geochemical reactions occurring during shale fracturing which will impact produced water reuse, scale inhibitor selection to prevent inorganic scale deposition resulting in better fracture performance.
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Zheng, Shuang, and Mukul Sharma. "An Integrated Equation-of-State Compositional Hydraulic Fracturing and Reservoir Simulator." In SPE Annual Technical Conference and Exhibition. Society of Petroleum Engineers, 2020. http://dx.doi.org/10.2118/201700-ms.

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Kortam, Mostafa Mahmoud, Samir Siso, Nelly Mohamed Abbas, et al. "Significant Production Improvement of UltraLow Permeability Granitic Reservoirs to Develop Heavy Black Oil, Utilizing Channel Fracturing Technique." In SPE/AAPG Africa Energy and Technology Conference. SPE, 2016. http://dx.doi.org/10.2118/afrc-2575150-ms.

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ABSTRACT The development of low quality reservoirs such as; low permeability, marginal assets, and unconventional resources has a several cost challenges pushing the industry toward maximizing the potentiality and optimizing the strategies of such high risk plays. Petrobel has a discovered one of such challenged asset and successfully conducted a comprehensive study to set the best development strategy to unleash this potential. SIDRI Area is a relatively new settlement with a reasonable hydrocarbon potential according to petrophysical analysis. The target formation of SIDRI wells is a sedimentary rock with granitic facies that consist of a series of tight conglomerates over an oil/water column of more than 900m. The pore system of this rigid and stiff formation consists of a micro natural fractures network with secondary cemented porosity. The production is mainly governed these tiny natural fractures that have a permeability as low as 0.1-0.5 md. Despite this tightness these series are separated by nonporous sections that occasionally exhibit as barrier and may introduce layering or subdivision of pay, however in sometimes permit a vertical communication between productive sections. Performed Cuttings analysis such as XRD, thin-sections showed a variety of minerals composition representing different lithology which in turn complicates the characterization of such reservoir. On top of the unique mineralogy, the executions of fracturing treatment of SIDRI wells include multiple other challenges. The higher reservoir temperature and the formation depth cause a great constraint in terms of pumping rate and pressure. Besides, the non-availability of pumping equipment of high Horsepower restricts the pump rates and also limits the utilization of slick water frac. Even the nature and the quality of crude oil is quite challenged since it is a heavy black oil type and its composition contains high number of asphaltenic compounds accordingly the opportunity of creating sludge with treatment fluids is highly likely. The oil water viscosity ratio at reservoir condition represents a weighted obstacle for oil recovery that should be overcome. The basic concept of applying hydraulic fracturing for these kinds of reservoirs is very simple, however the execution to get much more production improvement is quite difficult. Particularly the main idea here is to conduct a cost effective fracturing treatment with economical wisdom principle that can lead to achieve a greater oil recovery with best profitable model. This paper presents the details of formation characterization and reservoir quality assessment, as well as a detailed discussion about wettability alteration and how adversely complicates the process of determining initial saturation. The implemented application including designing, experimental works, and execution of the channel fracture treatment job will be reviewed. The work sequence of this project that led to commercialize such asset will be addressed too.
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Hsu, Yun, Xinglai Dang, Warren Chilton, et al. "New Physics-Based 3D Hydraulic Fracture Model." In SPE Hydraulic Fracturing Technology Conference. Society of Petroleum Engineers, 2012. http://dx.doi.org/10.2118/152525-ms.

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Shah, Koras, Robert Frank Shelley, Deepak Gusain, Lyle V. Lehman, Amir Mohammadnejad, and Matthew T. Conway. "Development of the Brittle Shale Fracture Network Model." In SPE Hydraulic Fracturing Technology Conference. Society of Petroleum Engineers, 2013. http://dx.doi.org/10.2118/163829-ms.

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