Bibliographies thématiques / Fracturing fluids

Littérature scientifique sur le sujet « Fracturing fluids »

Auteur : Grafiati
Publié le 10 mars 2023

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Articles de revues sur le sujet "Fracturing fluids"

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Ovchinnikov, V. P., D. S. Gerasimov, P. V. Ovchinnikov, Ya M. Kurbanov et A. F. Semenenko. « ANALYSIS OF THE EFFICIENCY OF USING BIOPOLYMERS FOR HYDRAULIC FRACTURING FLUIDS ». Oil and Gas Studies, no 3 (1 juillet 2017) : 76–80. http://dx.doi.org/10.31660/0445-0108-2017-3-76-80.

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Hydraulic fracturingis the most appropriate technological method of stimulating reservoir fluid inflow into the well bore. The efficiency of this method is determined by the properties of disperse and dispersion media. The article gives analysis of various types of fracturing fluids and shows promising applications of biopolymer dispersion media. The authors proposed a composition of fracturing fluids with a biopolymer and destructor.
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Wilk, Klaudia. « Experimental and Simulation Studies of Energized Fracturing Fluid Efficiency in Tight Gas Formations ». Energies 12, no 23 (23 novembre 2019) : 4465. http://dx.doi.org/10.3390/en12234465.

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The use of water-based fracturing fluids during fracturing treatment can be a problem in water-sensitive formations due to the permeability damage hazard caused by clay minerals swelling. The article includes laboratory tests, analyses and simulations for nitrogen foamed fracturing fluids. The rheology and filtration coefficients of foamed fracturing fluids were examined and compared to the properties of conventional water-based fracturing fluid. Laboratory results provided the input for numerical simulation of the fractures geometry for water-based fracturing fluids and 50% N2 foamed fluids, with addition of natural, fast hydrating guar gum. The results show that the foamed fluids were able to create shorter and thinner fractures compared to the fractures induced by the non-foamed fluid. The simulation proved that the concentration of proppant in the fracture and its conductivity are similar or slightly higher when using the foamed fluid. The foamed fluids, when injected to the reservoir, provide additional energy that allows for more effective flowback, and maintain the proper fracture geometry and proppant placing. The results of laboratory work in combination with the 3D simulation showed that the foamed fluids have suitable viscosity which allows opening the fracture, and transport the proppant into the fracture, providing successful fracturing operation. The analysis of laboratory data and the performed computer simulations indicated that fracturing fluids foamed by nitrogen are a good alternative to non-foamed fluids. The N2-foamed fluids exhibit good rheological parameters and proppant-carrying capacity. Simulated fracture of water-based fracturing fluid is slightly longer and higher compared to foamed fluid. At the same time, when using a fluid with a gas additive, the water content in fracturing fluid is reduced which means the minimization of the negative results of the clay minerals swelling.
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Wang, Yi Dan, et Hong Fu Fan. « Research on and Application of Clean Fracturing Fluids in Coal-Bed Methane ». Advanced Materials Research 1092-1093 (mars 2015) : 212–15. http://dx.doi.org/10.4028/www.scientific.net/amr.1092-1093.212.

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The development history of fracturing fluids is reviewed, the compositions and action mechanisms of the clean fracturing fluid systems used currently are analyzed, the recent research and application of the clean fracturing fluids in coal—bed methane production are summarized, and the development trend of clean fracturing fluids is presented in this paper.
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Chen, Hai Hui, Hong Fu Fan, Jian Ping Guo, Meng Tang et Fei Ni. « Evaluation and Prediction of Coalbed Gas Fracturing Fluid ». Advanced Materials Research 1008-1009 (août 2014) : 257–63. http://dx.doi.org/10.4028/www.scientific.net/amr.1008-1009.257.

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There is a wide variety of coalbed gas fracturing fluids. It’s important that choose suitable fracturing fluids for different kinds of formations. We summed up the advantages and disadvantages of each type of fracturing fluid by analyzing and comparing different types of fracturing fluid, and produced a performance comparison table between each type. Pointed out that the existing problems and solutions of fracturing fluid in coalbed and envisaged the future trends.
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Zheng, Shuang, et Mukul M. Sharma. « Modeling Hydraulic Fracturing Using Natural Gas Foam as Fracturing Fluids ». Energies 14, no 22 (16 novembre 2021) : 7645. http://dx.doi.org/10.3390/en14227645.

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Stranded gas emission from the field production because of the limitations in the pipeline infrastructure has become one of the major contributors to the greenhouse effects. How to handle the stranded gas is a troublesome problem under the background of global “net-zero” emission efforts. On the other hand, the cost of water for hydraulic fracturing is high and water is not accessible in some areas. The idea of using stranded gas in replace of the water-based fracturing fluid can reduce the gas emission and the cost. This paper presents some novel numerical studies on the feasibility of using stranded natural gas as fracturing fluids. Differences in the fracture creating, proppant placement, and oil/gas/water flowback are compared between natural gas fracturing fluids and water-based fracturing fluids. A fully integrated equation of state compositional hydraulic fracturing and reservoir simulator is used in this paper. Public datasets for the Permian Basin rock and fluid properties and natural gas foam properties are collected to set up simulation cases. The reservoir hydrocarbon fluid and natural gas fracturing fluids phase behavior is modeled using the Peng-Robinson equation of state. The evolving of created fracture geometry, conductivity and flowback performance during the lifecycle of the well (injection, shut-in, and production) are analyzed for the gas and water fracturing fluids. Simulation results show that natural gas and foam fracturing fluids are better than water-based fracturing fluids in terms of lower breakdown pressure, lower water leakoff into the reservoir, and higher cluster efficiency. NG foams tend to create better propped fractures with shorter length and larger width, because of their high viscosity. NG foam is also found to create better stimulated rock volume (SRV) permeability, better fracturing fluid flowback with a large water usage reduction, and high natural gas consumption. The simulation results presented in this paper are helpful to the operators in reducing natural gas emission while reducing the cost of hydraulic fracturing operation.
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Wilk-Zajdel, Klaudia, Piotr Kasza et Mateusz Masłowski. « Laboratory Testing of Fracture Conductivity Damage by Foam-Based Fracturing Fluids in Low Permeability Tight Gas Formations ». Energies 14, no 6 (23 mars 2021) : 1783. http://dx.doi.org/10.3390/en14061783.

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In the case of fracturing of the reservoirs using fracturing fluids, the size of damage to the proppant conductivity caused by treatment fluids is significant, which greatly influence the effective execution of hydraulic fracturing operations. The fracturing fluid should be characterized by the minimum damage to the conductivity of a fracture filled with proppant. A laboratory research procedure has been developed to study the damage effect caused by foamed and non-foamed fracturing fluids in the fractures filled with proppant material. The paper discusses the results for high quality foamed guar-based linear gels, which is an innovative aspect of the work compared to the non-foamed frac described in most of the studies and simulations. The tests were performed for the fracturing fluid based on a linear polymer (HPG—hydroxypropyl guar, in liquid and powder form). The rheology of nitrogen foamed-based fracturing fluids (FF) with a quality of 70% was investigated. The quartz sand and ceramic light proppant LCP proppant was placed between two Ohio sandstone rock slabs and subjected to a given compressive stress of 4000–6000 psi, at a temperature of 60 °C for 5 h. A significant reduction in damage to the quartz proppant was observed for the foamed fluid compared to that damaged by the 7.5 L/m3 natural polymer-based non-foamed linear fluid. The damage was 72.3% for the non-foamed fluid and 31.5% for the 70% foamed fluid, which are superior to the guar gum non-foamed fracturing fluid system. For tests based on a polymer concentration of 4.88 g/L, the damage to the fracture conductivity by the non-foamed fluid was 64.8%, and 26.3% for the foamed fluid. These results lead to the conclusion that foamed fluids could damage the fracture filled with proppant much less during hydraulic fracturing treatment. At the same time, when using foamed fluids, the viscosity coefficient increases a few times compared to the use of non-foamed fluids, which is necessary for proppant carrying capacities and properly conducted stimulation treatment. The research results can be beneficial for optimizing the type and performance of fracturing fluid for hydraulic fracturing in tight gas formations.
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Gaurina-Međimurec, Nediljka, Vladislav Brkić, Matko Topolovec et Petar Mijić. « Fracturing Fluids and Their Application in the Republic of Croatia ». Applied Sciences 11, no 6 (21 mars 2021) : 2807. http://dx.doi.org/10.3390/app11062807.

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Hydraulic fracturing operations are performed to enhance well performance and to achieve economic success from improved production rates and the ultimate reserve recovery. To achieve these goals, fracturing fluid is pumped into the well at rates and pressures that result in the creation of a hydraulic fracture. Fracturing fluid selection presents the main requirement for the successful performance of hydraulic fracturing. The selected fracturing fluid should create a fracture with sufficient width and length for proppant placement and should carry the proppant from the surface to the created fracture. To accomplish all those demands, additives are added in fluids to adjust their properties. This paper describes the classification of fracturing fluids, additives for the adjustment of fluid properties and the requirements for fluid selection. Furthermore, laboratory tests of fracturing fluid, fracture stimulation design steps are presented in the paper, as well as a few examples of fracturing fluids used in Croatia with case studies and finally, hydraulic fracturing performance and post-frac well production results. The total gas production was increased by 43% and condensate production by 106% in selected wells including wellhead pressure, which allowed for a longer production well life.
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Mihail, Silin, Magadova Lyubov, Malkin Denis, Krisanova Polina, Borodin Sergei et Filatov Andrey. « Applicability Assessment of Viscoelastic Surfactants and Synthetic Polymers as a Base of Hydraulic Fracturing Fluids ». Energies 15, no 8 (13 avril 2022) : 2827. http://dx.doi.org/10.3390/en15082827.

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Hydraulic fracturing (HF) is currently the most widespread and effective method of oil production stimulation. The most commonly used fracturing fluid is crosslinked guar gels. However, when using these systems, problems such as clogging of the pore space, cracking, and proppant packing with the remains of the undestroyed polymer arise. Therefore, the efficiency of the hydraulic fracturing process decreases. In this work, compositions based on viscoelastic surfactants (VES) and synthetic polymers (SP) were considered as alternatives capable of minimizing these disadvantages. Most often, the possibility of using a composition as a fracturing fluid is evaluated using rotational viscometry. However, rotational viscometry is not capable of fully assessing the structural and mechanical properties of fracturing fluid. This leads to a reduced spread of systems based on VES and SP. This paper proposes an integrated approach to assessing the effectiveness of a water-based fracturing fluid. The proposed comprehensive approach includes an assessment of the main characteristics of water-based fracturing fluids, including an analysis of their structural and mechanical properties, which is based on a combination of rotational and oscillatory rheology and a comparative analysis of methods for studying the influence of fluids on the reservoir rock. The use of the developed approach to assess the technological properties of fracturing fluids makes it possible to demonstrate the potential applicability of new, unconventional fracturing fluids such as systems based on VES and SP.
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Ramadhan, Dimas, Hidayat Tulloh et Cahyadi Julianto. « Analysis Study Of The Effect In Selecting Combination Of Fracturing Fluid Types And Proppant Sizes On Folds Of Increase (FOI) To Improve Well Productivity ». Journal of Petroleum and Geothermal Technology 1, no 2 (26 novembre 2020) : 92. http://dx.doi.org/10.31315/jpgt.v1i2.3886.

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As fracturing materials, fracturing fluid and proppant are two very important parameters in doing hydraulic fracturing design. The combination of fractuirng fluid and proppant selection is the main focus and determinant of success in the hydraulic fracturing process. The high viscosity of the fracturing fluid will make it easier for the proppant to enter to fill the fractured parts, so that the conductivity of the fractured well will be better and can increase the folds of increase (FOI) compared to fracturing fluid with lower viscosity (Economides, 2000). This research was conducted by using the sensitivity test method on the selection of fracturing fluid combinations carried out at the TX-01 well with various sizes of proppants (namely; 12/18, 16/20, and 20/40 mesh) with the proppant selected being ceramic proppant type carbolite performed using the FracCADE simulator. Fracturing fluid was selected based on its viscosity, namely YF240OD and PrimeFRAC20 fluids with viscosity value of 4.123 cp and 171.1 cp, with a fixed pump rate of 14 bpm. The results showed that the combination of high-viscosity fluids (PrimeFRAC20) and 16/20 mesh proppant size resulted in a greater incremental fold (FOI) between the choice of another combination fracturing fluids and proppant sizes, namely 6.25.
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Shevtsova, Anna, Sergey Stanchits, Maria Bobrova, Egor Filev, Sergey Borodin, Vladimir Stukachev et Lyubov Magadova. « Laboratory Study of the Influence of Fluid Rheology on the Characteristics of Created Hydraulic Fracture ». Energies 15, no 11 (24 mai 2022) : 3858. http://dx.doi.org/10.3390/en15113858.

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In the last decade, the negative impact of hydraulic fracturing fluids on the reservoir properties has been noted, which has led to the new trend of improving characteristics and developing new hydraulic fracturing fluids. As an alternative option to the traditionally used cross-linked fluids based on guar solution, in our laboratory we have tested fluids having a branched spatial structure, which allowed them to hold and transport proppants, despite the low viscosity of this kind of fluids (100–200 mPa·s measured at 100 s−1). Existing theoretical models of hydraulic fracture (HF) propagation have some limitations in predicting the influence of fracturing fluids on reservoir properties. Unfortunately, in situ experiments in the target reservoir are difficult and expensive. Thus, laboratory experiments can be considered as a reasonable alternative for testing new fluids, since they can provide comprehensive information about the properties of the created HF before the application of a new hydraulic fracturing technique in the field conditions. This paper presents the results of an experimental study of hydraulic fracturing of granite samples in laboratory conditions. The injection of water- and oil-based unconventional fracturing fluids was performed to study the influence of fluid rheology on the dynamics of the hydraulic fracture propagation process and parameters of the created HF. We have found that the fracturing fluid viscosity affects the parameters of the created HF, such as aperture, propagation velocity, breakdown pressure, and HF surface tortuosity. The obtained relationships can be taken into account for Hydraulic Fracture modelling, which may increase the efficiency of the hydraulic fracturing in the field conditions.
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Thèses sur le sujet "Fracturing fluids"

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Kekacs, Daniel. « Treatment and Characterization of Hydraulic Fracturing Fluids ». The Ohio State University, 2014. http://rave.ohiolink.edu/etdc/view?acc_num=osu1406297620.

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Cluff, Maryam Ansari. « Microbial Aspects of Shale Flowback Fluids and Response to Hydraulic Fracturing Fluids ». The Ohio State University, 2013. http://rave.ohiolink.edu/etdc/view?acc_num=osu1366292190.

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Heyob, Katelyn M. « The Biodegradability of Polypropylene Glycols and Ethoxylated Surfactants within Hydraulic Fracturing Fluids ». The Ohio State University, 2015. http://rave.ohiolink.edu/etdc/view?acc_num=osu1440415027.

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Liu, Shuai. « Laboratory Investigations on the Geochemical Response of Groundwater-sediment Environment to Hydraulic Fracturing Fluids ». The Ohio State University, 2013. http://rave.ohiolink.edu/etdc/view?acc_num=osu1376501759.

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O'Keeffe, Niall. « Fluid-driven fractures in elastic hydrogels : propagation and coalescence ». Thesis, University of Cambridge, 2019. https://www.repository.cam.ac.uk/handle/1810/287633.

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In this thesis we focus on a novel experimental exploration of fluid-driven fractures in a brittle hydrogel matrix. Fluid-driven fracturing is a procedure by which a fracture is initiated and propagates due to pressure applied by a fluid introduced inside the fracture. We describe how to construct the experimental setup utilised in this research, including how to synthesise polyacrylamide hydrogels to study the processes linked with fluid-driven fracturing. These transparent, linearly elastic and brittle gels permit fracturing at low pressures and speeds allowing accurate measurements to be obtained. The broad range of modulus and fracture energy values attainable from this medium allow the exploration of particular regimes of importance. Fracturing within these hydrogels also creates beautiful spiral patterns on the plastically deformed surfaces. We analyse these patterns and discuss their formation, while also commenting on their fractal-like nature. Initially, we study single fractures that are driven by an incompressible Newtonian fluid, injected at a constant rate into an elastic matrix. The injected fluid creates a radial fracture that propagates along a plane. We investigate this type of fracture theoretically and then verify the scaling predictions experimentally. We examine the rate of radial crack growth, fracture aperture, shape of the crack tip and internal fluid flow field. We exhibit the existence of two distinct fracturing regimes, and the transition between these, in which propagation is either dominated by viscous flow within the fracture or the material toughness. Particle image velocimetry measurements also strikingly show that the flow in the fracture can alter from an expected radial symmetry to circulation cells, dependent on the regime of propagation. We then expand our research to the problem of two coplanar fluid-driven radial fractures. This was chosen to focus on the physical mechanisms that are key to fracture network formation, related to many geophysical and industrial practices. Initially, the two fractures propagate independently of each other. At a critical separation they begin to interact, with non-uniform growth occurring along the fracture edges due to the evolving stress state in the gel matrix. When the radial extents of the fractures become sufficiently large, they coalesce and form a bridge between them. Following initial contact, a large increase in flow is seen into the newly created bridge and most of the growth is localised along this, perpendicular to the line connecting the injection sources. From experimental measurements, we observe a universal dynamic behaviour for the growth of this bridge. We model this universal behaviour theoretically and construct scalings related to the growth after coalescence, which again identifies both a viscous and toughness regime. The toughness regime is verified experimentally for the bridge growth and the universal shape of the thickness profile along the bridge. The coalesced fractures then transition into a single fracture at late times. Finally, we discuss a number of other interesting scenarios that may occur such as, non-coalescing fractures, asymmetric coalescence and ridge formation.
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Ohanian, Nicholas. « The Examination of Fiber and Breaker Effects on the Rheological and Settling Rate Characteristics of Hydraulic Fracturing Fluids ». The Ohio State University, 2014. http://rave.ohiolink.edu/etdc/view?acc_num=osu1417610323.

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Rocco, Stefano. « Some geological implications of the flow of clay-water mixtures ». Thesis, University of Cambridge, 2017. https://www.repository.cam.ac.uk/handle/1810/270525.

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This thesis investigates three problems in the general area of environmental fluid mechanics. The first two problems are related to liquid or gas flow through clay-water suspensions, with relevance for the underground storage of radioactive waste and also for understanding the mechanism of eruption in mud volcanoes. The third problem centres on the different problem of mixing in a turbulent buoyant plume. First, the injection of gas and water from a central source into a two-dimensional layer of clay confined between two circular horizontal plates is investigated. This provides a model of the potential pressurisation and failure of the seal rock around a radioactive waste repository as may arise if gas is continuously generated in the repository. As the gas injection pressure is gradually increased the cell walls deform and the clay moves radially outwards. However, at a critical radius, the liquid-clay interface becomes unstable and a series of channels propagate through the clay. When one of the channels reaches the edge of the domain the gas escapes and the pressure is released. As a result, the domain relaxes by elastic deformation and the clay seals the channel. In this way, continuous fluid injection leads to episodic release of gas from the cell. The second problem concerns the flow of mud along a vertical conduit driven by the combined effect of reservoir pressure and buoyancy associated with the gas injected at the base of the conduit. This represents an analogue model of the eruption of a mud volcano, in which mud rises from a deep reservoir to the surface. I find that the pressure associated with the reservoir and any buoyancy force produced by the migration of gas from deep in the reservoir to the surface leads to a continuous eruption if the net pressure is greater than the yield stress of the clay. If the reservoir pressure falls during such an event, the eruption will eventually stop, once the pressure reaches a dynamic yield stress condition. Only later, if the reservoir pressure increases to the static yield stress of the clay will the eruption start again, and this can lead to a series of eruption cycles which depend on the non-Newtonian rheology of the clay. In contrast, if this pressure is smaller than the yield stress of the clay, a series of episodic gas burst events can occur until the conduit is cleared of mud. The third problem relates to the mixing in a turbulent buoyant plume. Through a series of new experiments and some complementary theoretical modelling I show that the mixing in a turbulent plume is strongly affected by the eddies and leads to significant longitudinal dispersion in the flow. The implications of the modelling for determining the residence time distribution of the fluid in the plume is discussed.
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Salardon, Roland. « Fracturation, interactions fluides-roches et circulations fluides dans un bassin en hyper-extension puis lors de son inversion : Exemple des séries mésozoïques de la Zone Nord Pyrénéenne (Chainons Béarnais, France) ». Thesis, Université de Lorraine, 2016. http://www.theses.fr/2016LORR0342/document.

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Les interactions entre la fracturation, les circulations fluides et la chimie des fluides au sein de marges hyper-étendues sont encore peu décrites et sont pour la plupart localisées en mer, enfouies sous des sédiments post-rift. Le bassin sud Aquitain et la partie nord des Pyrénées constituent un cas d’étude approprié pour l’investigation de ces interactions dans un modèle de marge hyper-étendue avec exhumation du manteau durant le Crétacé inférieur puis inversée. Les données de terrain ont permis de décrire trois principaux sets de fractures. Ils ont été corrélés aux principaux événements de l’évolution géodynamique du bassin correspondant au rifting triasique, à l’hyper-extension datée Aptien-Cénomanien, et à la compression pyrénéenne. Les observations pétrographiques, les analyses Raman et microthermométriques sur les inclusions fluides, les données acquises par ICP-MS, et les analyses isotopiques ont permis de déterminer les chimies, les températures, les conditions rédox, les compositions des gaz, les signatures isotopiques de l’oxygène et du carbone, et les teneurs en terres rares des fluides parents pour les ciments précipités durant chaque épisode. Ces données ont permis le calage temporel des évènements diagénétiques majeurs. En particulier, la dolomie baroque et la chlorite ont précipité dans les fractures du set 2 durant l’hyper-extension correspondant au pic thermique à des températures supérieures à 300°C. La signature isotopique, la forte teneur en CO2, l’occurrence de H2S et les fortes salinités des fluides parents suggèrent la percolation de fluides mantelliques ascendants au travers des évaporites triasiques. La phase fin et post hyper-extension est caractérisée par de la bréchification hydraulique dans les formations les plus poreuses, une baisse des températures et des salinités, une baisse de la contribution mantellique dans les fluides parents, une fermeture du système diagénétique au cours de l’enfouissement et un passage à des conditions réductrices durant la précipitation du quartz, de la pyrite et de la calcite. La phase de compression pyrénéenne associée au troisième stade de fracturation a induit une réouverture du système diagénétique et favorisé le retour à des conditions oxydantes et à des infiltrations de fluides météoriques
Interactions between fracturing, fluid circulations and fluid chemistry on hyper-extended margins is still poorly described as most of them are located offshore, buried underneath post-rift sediments. The southern Aquitaine basin and the northern Pyrenees constitute an appropriate case study to investigate these interactions since a model of hyper extended margin with mantle exhumation during the Lower Cretaceous subsequently inverted was recently proposed. From a field study, we here describe three main sets of fractures (set 1 to set 3). They are correlated with main stages of the geodynamic evolution of the basin corresponding to the Liassic rifting, the Aptian-Cenomanian hyper-extension, and the Pyrenean compression. Petrographic observations, Raman and micro-thermometry analysis on fluid inclusions, ICP-MS, and isotope analysis permitted to determine chemistries, temperatures, redox conditions, gas compositions, oxygen and carbon isotopic signatures, and REE contents of parent fluids for cements precipitated during each episode. In particular saddle dolomite and chlorite precipitated in set 2 fractures during the hyper-extension corresponding to the thermal peak at temperatures higher than 300°C. The isotopic signature, the high CO2 content, the occurrence of H2S and the high salinity of parent fluids suggest ascending mantle fluids percolating across Triassic evaporites. The late and post hyper-extensional phase is characterized by hydraulic brecciation in porous formations, a decrease in temperature and salinity, a decrease in mantle contribution in parent fluids, a closing of the diagenetic system during burial and a switch to reducing conditions during the precipitation of quartz, pyrite and calcite. The Pyrenean compressive phase associated with the third fracturing stage induced a reopening of the diagenetic system and favored a return to oxidizing conditions and infiltrations of meteoric fluids
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Eljarray, Abdelali. « Circulations fluides et altérations hydrothermales associées à des dépôts U (As, F) dans le massif de Saint Sylvestre (NW du massif central français) ». Vandoeuvre-les-Nancy, INPL, 1993. http://www.theses.fr/1993INPL009N.

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Ce travail consacre à l'étude des transferts de l'uranium aux différents stades hydrothermaux dans le massif de saint sylvestre (NW du M. C. F. ), et aux caractéristiques des perturbations d'ordre géochimique, minéralogique et structural qui leur sont associées, a été réalisée grâce à une approche pluridisciplinaire. Il a permis de connaitre: (1) la remobilisation tardive d'uranium hors du gisement et son ampleur; (2) les relations entre les différentes phases d'altération et la minéralisation primaire qui se traduisent par des marqueurs spécifiques et des orientations de réseaux de micro à macro-fracturation; (3) les conditions et la géométrie de développement des différents stades d'altération grâce à l'étude des fluides liées à ces stades. L'étude simultanée des circulations fluides, de la microfissuration et des altérations associées, a permis de: (1) envisager un développement des pièges d'uranium episyenite dans un système de fractures e-w, par un mécanisme de condensation de fluide aqueux type VW dont les caractéristiques sont, une faible salinité (<2% pds eq. Nacl) et une température élevée (350 a 400c); (2) définir les caractéristiques physicochimiques des fluides associes aux stades précoces à tardifs par rapport a la minéralisation uranifère. En effet, les stades précoces, sont caractérises par des fluides aquo-carboniques assez comparables (300 a 350c, salinité comprise entre 6 et 14% pds eq. Nacl) et par différents stades de piégeages de fluides aqueux
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Chang, Hong. « Hydraulic Fracturing in Particulate Materials ». Diss., Georgia Institute of Technology, 2004. http://hdl.handle.net/1853/4957.

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For more than five decades, hydraulic fracturing has been widely used to enhance oil and gas production. Hydraulic fracturing in solid materials (e.g., rock) has been studied extensively. The main goal of this thesis is a comprehensive study of the physical mechanisms of hydraulic fracturing in cohesionless sediments. For this purpose, experimental techniques are developed to quantify the initiation and propagation of hydraulic fractures in dry particulate materials. We have conducted a comprehensive experimental series by varying such controlling parameters as the properties of particulate materials and fracturing fluids, boundary conditions, initial stress states, and injection volumes and rates. In this work, we suggest principle fundamental mechanisms of hydraulic fracturing in particulate materials and determine relevant scaling relationships (e.g., the interplay between elastic and plastic processes). The main conclusion of this work is that hydraulic fracturing in particulate materials is not only possible, but even probable if the fluid leak-off is minimized (e.g., high flow rate, high viscosity, low permeability). Another important conclusion of this work is that all parts of the particulate material are likely to be in compression. Also, the scale effect (within the range of the laboratory scales) appears to be relatively insignificant, that is, the observed features of fractures of different sizes are similar. Based on the observed fracture geometries, and injection pressures we suggested three models of hydraulic fracturing in particulate materials. In the cavity expansion or ??e driving model, the fracturing fluid is viewed as a sheet pile (blade) that disjoints the host material, and the cavity expansion occurs at the fracture (blade) front. The shear banding model is also consistent with a compressive stress state everywhere in the particulate material and explains the commonly observed beveled fracture front. The model of induced cohesion is based on the fluid leak-off ahead of the fracture front. The induced cohesion may be caused by the tensile strain near the fracture tip (where the stress state is also compressive), which, in turn, induces the cavitation of the leaked-off fluid and hence capillary forces.
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Livres sur le sujet "Fracturing fluids"

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L, Tracy Linda, Wilson William K et United States. Forest Service. Northern Research Station, dir. Chloride concentration gradients in tank-stored hydraulic fracturing fluids following flowback. Newtown Square, PA : U.S. Dept. of Agriculture, Forest Service, Northern Research Station, 2011.

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B, Jamtveit, et Yardley B. W. D, dir. Fluid flow and transport in rocks : Mechanisms and effects. London : Chapman & Hall, 1997.

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Hydraulic Fracturing Chemicals And Fluids Technology. Elsevier Science & Technology, 2013.

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Hydraulic Fracturing Chemicals and Fluids Technology. Elsevier, 2013. http://dx.doi.org/10.1016/c2012-0-02544-6.

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Hydraulic Fracturing Chemicals and Fluids Technology. Elsevier, 2020. http://dx.doi.org/10.1016/c2019-0-04571-2.

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Fink, Johannes. Hydraulic Fracturing Chemicals and Fluids Technology. Elsevier Science & Technology, 2020.

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Parihar, Narendra. Hydraulic Fracturing Chemicals and Fluids Technology. Scitus Academics LLC, 2016.

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Fink, Johannes. Hydraulic Fracturing Chemicals and Fluids Technology. Elsevier Science & Technology Books, 2013.

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Hydraulic Fracturing Chemicals and Fluids Technology. Elsevier Science & Technology Books, 2020.

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Maffia, G. J. Mining Natural Gas : Introduction to Hydraulic Fracturing Fluids, Proppants and Processing. Wiley & Sons, Incorporated, John, 2020.

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Chapitres de livres sur le sujet "Fracturing fluids"

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Dai, Caili, et Fulin Zhao. « Fracturing Fluids and Fracturing Fluid Additives ». Dans Oilfield Chemistry, 237–57. Singapore : Springer Singapore, 2018. http://dx.doi.org/10.1007/978-981-13-2950-0_8.

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Yang, Zhenning, et Carlton L. Ho. « Contaminated High-Plasticity Clay by Hydraulic Fracturing Fluids ». Dans Proceedings of GeoShanghai 2018 International Conference : Geoenvironment and Geohazard, 567–74. Singapore : Springer Singapore, 2018. http://dx.doi.org/10.1007/978-981-13-0128-5_62.

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Sagala, Farad, et Nashaat N. Nassar. « Nanoparticles for Drilling, Cementing, Hydraulic Fracturing, and Well Stimulation Fluids ». Dans Lecture Notes in Nanoscale Science and Technology, 359–80. Cham : Springer International Publishing, 2021. http://dx.doi.org/10.1007/978-3-319-12051-5_10.

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Struchtemeyer, Christopher G., Noha H. Youssef et Mostafa S. Elshahed. « Protocols for Investigating the Microbiology of Drilling Fluids, Hydraulic Fracturing Fluids, and Formations in Unconventional Natural Gas Reservoirs ». Dans Springer Protocols Handbooks, 133–56. Berlin, Heidelberg : Springer Berlin Heidelberg, 2014. http://dx.doi.org/10.1007/8623_2014_8.

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Pal, Nilanjan, et Amit Verma. « Applications of Surfactants as Fracturing Fluids : Chemical Design, Practice, and Future Prospects in Oilfield Stimulation Operations ». Dans Surfactants in Upstream E&P, 331–55. Cham : Springer International Publishing, 2021. http://dx.doi.org/10.1007/978-3-030-70026-3_12.

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Xiao, Xiaolong, Mingxiu Yao, Chao Xie, Zhen Wu, Yaoyao Wei, Zhenjiang Zhao, Huajian Wang, Youle Liu et Bing Liu. « Numerical Simulation of Separation Mechanism in V-Shaped Outlet Hydrocyclone for Coalbed Gas Fracturing Flow-Back Fluids ». Dans Lecture Notes in Electrical Engineering, 41–49. Singapore : Springer Singapore, 2021. http://dx.doi.org/10.1007/978-981-33-6318-2_5.

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Awejori, Gabriel, Havila Jupudi, Cody Massion et Mileva Radonjic. « Study on Advanced Cementing Practices Using Inert Graphene Nanoplatelets and Hydraulic Fracturing Fluids for Wellbore Integrity and Sustainability ». Dans The Minerals, Metals & ; Materials Series, 1225–36. Cham : Springer Nature Switzerland, 2023. http://dx.doi.org/10.1007/978-3-031-22524-6_117.

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« Fracturing Fluids ». Dans Handbook of Hydraulic Fracturing, 165–94. Hoboken, NJ : John Wiley & Sons, Inc, 2016. http://dx.doi.org/10.1002/9781119225102.ch6.

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« Fracturing Fluids ». Dans Water-Based Chemicals and Technology for Drilling, Completion, and Workover Fluids, 115–78. Elsevier, 2015. http://dx.doi.org/10.1016/b978-0-12-802505-5.00003-2.

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« Fracturing fluids ». Dans Petroleum Engineer's Guide to Oil Field Chemicals and Fluids, 567–651. Elsevier, 2015. http://dx.doi.org/10.1016/b978-0-12-803734-8.00017-5.

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Actes de conférences sur le sujet "Fracturing fluids"

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Ribeiro, Lionel, et Mukul Mani Sharma. « Multi-Phase Fluid-Loss Properties and Return Permeability of Energized Fracturing Fluids ». Dans SPE Hydraulic Fracturing Technology Conference. Society of Petroleum Engineers, 2011. http://dx.doi.org/10.2118/139622-ms.

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Kakadjian, Sarkis, Joseph Thompson et Robert Torres. « Fracturing Fluids from Produced Water ». Dans SPE Production and Operations Symposium. Society of Petroleum Engineers, 2015. http://dx.doi.org/10.2118/173602-ms.

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Harris, Phillip C., et Stanley J. Heath. « High-Quality Foam Fracturing Fluids ». Dans SPE Gas Technology Symposium. Society of Petroleum Engineers, 1996. http://dx.doi.org/10.2118/35600-ms.

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Gupta, D. V. Satya. « Unconventional Fracturing Fluids for Tight Gas Reservoirs ». Dans SPE Hydraulic Fracturing Technology Conference. Society of Petroleum Engineers, 2009. http://dx.doi.org/10.2118/119424-ms.

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Marquez, Maricel, Narongsak Tonmukayakul, Laura Anne Schafer, Matthew Bernard Zielinski, Paul Lord et Tonya L. Goosen. « High Pressure Testing of Borate Crosslinked Fracturing Fluids ». Dans SPE Hydraulic Fracturing Technology Conference. Society of Petroleum Engineers, 2012. http://dx.doi.org/10.2118/152593-ms.

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Putzig, Donald E., et Jerry D. St.Clair. « A New Delay Additive for Hydraulic Fracturing Fluids ». Dans SPE Hydraulic Fracturing Technology Conference. Society of Petroleum Engineers, 2007. http://dx.doi.org/10.2118/105066-ms.

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Walker, Michael L., Chris E. Shuchart, Joseph G. Yaritz et Lewis R. Norman. « Effects of Oxygen on Fracturing Fluids ». Dans SPE International Symposium on Oilfield Chemistry. Society of Petroleum Engineers, 1995. http://dx.doi.org/10.2118/28978-ms.

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Prud'homme, R. K., et J. K. Wang. « Filter-Cake Formation of Fracturing Fluids ». Dans SPE International Symposium on Oilfield Chemistry. Society of Petroleum Engineers, 1993. http://dx.doi.org/10.2118/25207-ms.

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Kakadjian, Sarkis, Joseph Earl Thompson, Jose Roberto Torres et H. Quintero. « Stable Fracturing Fluids From Waste Water ». Dans International Petroleum Technology Conference. International Petroleum Technology Conference, 2014. http://dx.doi.org/10.2523/iptc-18133-ms.

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Walters, Harold G., Ronnie G. Morgan et Phillip C. Harris. « Kinetic Rheology of Hydraulic Fracturing Fluids ». Dans SPE Annual Technical Conference and Exhibition. Society of Petroleum Engineers, 2001. http://dx.doi.org/10.2118/71660-ms.

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Rapports d'organisations sur le sujet "Fracturing fluids"

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Kingston, A. W., O. H. Ardakani, G. Scheffer, M. Nightingale, C. Hubert et B. Meyer. The subsurface sulfur system following hydraulic stimulation of unconventional hydrocarbon reservoirs : assessing anthropogenic influences on microbial sulfate reduction in the deep subsurface, Alberta. Natural Resources Canada/CMSS/Information Management, 2022. http://dx.doi.org/10.4095/330712.

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Hydraulic fracturing is a reservoir stimulation technique that involves the injection of high-pressure fluids to enhance recovery from unconventional hydrocarbon reservoirs. Often this involves the injection of surface waters (along with additives such as biocides) into formational fluids significantly different isotopic and geochemical compositions facilitating geochemical fingerprinting of these fluid sources. In some instances, the produced fluids experience an increase in hydrogen sulfide (H2S) concentration over the course of production resulting in an increased risk to health and safety, the environment, and infrastructure due to the toxic and corrosive nature of H2S. However, questions remain as to the origin and processes leading to H2S formation following hydraulic fracturing. In this study, we analyzed a series of produced waters following hydraulic fracturing of a horizontal well completed in the Montney Formation, Western Canada to evaluate variations in geochemical and microbiological composition over time and characterize potential sulfur species involved in the production of H2S. Initially, sulfur isotope ratios (d34S, VCDT) of dissolved sulfate in produced water had a baseline value of 27per mil similar to the d34S value of 25per mil for solid anhydrite derived from core material. Subsequently, d34S values of sulfate in produced fluids sequentially increased to 35per mil coincident with the appearance of sulfides in produced waters with a d34SH2S value of 18per mil. Oxygen isotope values of dissolved sulfate exhibited a synchronous increase from 13.2per mil to 15.8per mil VSMOW suggesting sulfate reduction commenced in the subsurface following hydraulic fracturing. Formation temperatures are &amp;lt;100°C precluding thermochemical sulfate reduction as a potential mechanism for H2S production. We suggest that microbial reduction of anhydrite-derived sulfate within the formation is likely responsible for the increase in H2S within produced waters despite the use of biocides within the hydraulic fracturing fluids. Initial assessments of microbial communities indicate a shift in community diversity over time and interactions between in situ communities and those introduced during the hydraulic fracturing process. This study indicates that biocides may not be fully effective in inhibiting microbial sulfate reduction and highlights the role anthropogenic influences such as hydraulic fracturing can have on the generation of H2S in the subsurface.
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Edwards, Pamela J., Linda L. Tracy et William K. Wilson. Chloride concentration gradients in tank-stored hydraulic fracturing fluids following flowback. Newtown Square, PA : U.S. Department of Agriculture, Forest Service, Northern Research Station, 2011. http://dx.doi.org/10.2737/nrs-rp-14.

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Reid, M. S., X. Wang, N. Utting et C. Jiang. Comparison of water chemistry of hydraulic-fracturing flowback water from two geological locations at the Duvernay Formation, Alberta, Canada. Natural Resources Canada/CMSS/Information Management, 2021. http://dx.doi.org/10.4095/329276.

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We analyzed and compared the water chemistry between 17 Fox Creek region samples, each from a different well, and 23 Three Hills region samples from a single well. Overall, the two regions were similar in chemical composition but showed small differences in some lower abundance dissolved elements. Additionally, we investigated changes in water chemistry of FPW over time from a single well. The majority of water quality parameters and water chemistry remained constant over the 7-month sampling time. Major ion chemistry showed increasing concentrations of Ca and Mg, and a decreasing concentration of SO4. Several trace elements also showed small trends of both increasing and decreasing concentrations over time. There was a strong correlation between Ca and Mg concentrations in both the Fox Creek region samples and Three Hills region samples, which is an indication of the mixing of formation water. However, the correlation between B and Sr was different among two region samples, which is likely due to the delayed mixing of formation water with the fracturing fluids during the flowback at different time periods of post fracturing. Likewise, Fox Creek region samples showed correlations between concentrations of Cl and Ca, Na and Ca, and Na and Mg, but these correlations were not seen in the Three Hills region samples. Geochemical modeling demonstrates that there are potential scales formed in the flowback water, but most of the minerals are still in the dissolution state in the formation. Stable isotopic analysis confirmed the mixing of injection water and the formation water.
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Skone, Timothy J. Fracturing Fluid Manufacturing. Office of Scientific and Technical Information (OSTI), février 2016. http://dx.doi.org/10.2172/1509379.

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Subhash Shah. FRACTURING FLUID CHARACTERIZATION FACILITY. Office of Scientific and Technical Information (OSTI), août 2000. http://dx.doi.org/10.2172/826022.

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Evans, R. D., J. C. Roegiers et J. Fagan. Fracturing fluid characterization facility (FFCF). Office of Scientific and Technical Information (OSTI), décembre 1993. http://dx.doi.org/10.2172/10128675.

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Farahbod, A. M., et J. F. Cassidy. Temporal variations in coda Q before and after the 2017 Barrow Strait earthquake (Mw 5.9) in Nunavut and the 2012 Haida Gwaii earthquake (Mw 7.8) in British Columbia. Natural Resources Canada/CMSS/Information Management, 2022. http://dx.doi.org/10.4095/331095.

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In this study, we examine potential temporal changes in coda Q values for two significant Canadian earthquakes in different tectonic environments: the 2017 (Mw 5.9) Barrow Strait earthquake along Canada's northern margin and the 2012 (Mw 7.8) Haida Gwaii subduction earthquake on Canada's west coast. Waveforms from 124 earthquakes (2.0 &amp;lt;/= M &amp;lt;/= 4.6) for ~30 years prior to the January 8, 2017 Barrow Strait earthquake and 66 events (mainly aftershocks of M 2.0-5.3) in about 4 years after the mainshock recorded by the closest seismic station (RES) of the Canadian National Seismograph Network (CNSN) were utilized in this study. Based on our analysis, overall average of Q0 (Q at 1 Hz) decreased from 92 (before the mainshock) to 81. The most significant decrease in the frequency range between 2 and 16 Hz is observed for areas corresponding to ellipse parameter a2 of 50, 70 and 80 mainly related to aftershock activity. Precursory Q changes could not be evaluated before the mainshock due to the lack of reported seismicity within 100 km of the recording seismic station for almost 2 years from April 2015 to January 2017. Coda Q values before and after the October 28, 2012 Haida Gwaii earthquake in British Columbia show a similar pattern. Waveforms from 249 earthquakes (2.0 &amp;lt;/= M &amp;lt;/= 4.9) in 2 years before the mainshock and 498 events (2.5 &amp;lt;/= M &amp;lt;/= 6.3) in 2 years after the mainshock recorded by the three closest seismic stations of the CNSN were utilized. Overall average of Q0 decreased from 89 (before the mainshock) to 69 (station BNB), from 90 to 79 (station DIB) and from 86 to 78 (station VIB). In general, these results are in agreement with other global studies that show a decrease in Q0 following a major earthquake, likely the result of increased fracturing and fluids in the epicentral region.
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Verba, Circe, et Aubrey Harris. Characterization of the Oriskany and Berea Sandstones : Evaluating Biogeochemical Reactions of Potential Sandstone–Hydraulic Fracturing Fluid Interaction. Office of Scientific and Technical Information (OSTI), juillet 2016. http://dx.doi.org/10.2172/1340996.

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Beck, Griffin. Final Report - Development and Field Testing Novel Natural Gas Surface Process Equipment for Replacement of Water as Primary Hydraulic Fracturing Fluid. Office of Scientific and Technical Information (OSTI), juin 2021. http://dx.doi.org/10.2172/1804085.

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Harris, L. B., P. Adiban et E. Gloaguen. The role of enigmatic deep crustal and upper mantle structures on Au and magmatic Ni-Cu-PGE-Cr mineralization in the Superior Province. Natural Resources Canada/CMSS/Information Management, 2021. http://dx.doi.org/10.4095/328984.

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Aeromagnetic and ground gravity data for the Canadian Superior Province, filtered to extract long wavelength components and converted to pseudo-gravity, highlight deep, N-S trending regional-scale, rectilinear faults and margins to discrete, competent mafic or felsic granulite blocks (i.e. at high angles to most regional mapped structures and sub-province boundaries) with little to no surface expression that are spatially associated with lode ('orogenic') Au and Ni-Cu-PGE-Cr occurrences. Statistical and machine learning analysis of the Red Lake-Stormy Lake region in the W Superior Province confirms visual inspection for a greater correlation between Au deposits and these deep N-S structures than with mapped surface to upper crustal, generally E-W trending, faults and shear zones. Porphyry Au, Ni, Mo and U-Th showings are also located above these deep transverse faults. Several well defined concentric circular to elliptical structures identified in the Oxford Stull and Island Lake domains along the S boundary of the N Superior proto-craton, intersected by N- to NNW striking extensional fractures and/or faults that transect the W Superior Province, again with little to no direct surface or upper crustal expression, are spatially associated with magmatic Ni-Cu-PGE-Cr and related mineralization and Au occurrences. The McFaulds Lake greenstone belt, aka. 'Ring of Fire', constitutes only a small, crescent-shaped belt within one of these concentric features above which 2736-2733 Ma mafic-ultramafic intrusions bodies were intruded. The Big Trout Lake igneous complex that hosts Cr-Pt-Pd-Rh mineralization west of the Ring of Fire lies within a smaller concentrically ringed feature at depth and, near the Ontario-Manitoba border, the Lingman Lake Au deposit, numerous Au occurrences and minor Ni showings, are similarly located on concentric structures. Preliminary magnetotelluric (MT) interpretations suggest that these concentric structures appear to also have an expression in the subcontinental lithospheric mantle (SCLM) and that lithospheric mantle resistivity features trend N-S as well as E-W. With diameters between ca. 90 km to 185 km, elliptical structures are similar in size and internal geometry to coronae on Venus which geomorphological, radar, and gravity interpretations suggest formed above mantle upwellings. Emplacement of mafic-ultramafic bodies hosting Ni-Cr-PGE mineralization along these ringlike structures at their intersection with coeval deep transverse, ca. N-S faults (viz. phi structures), along with their location along the margin to the N Superior proto-craton, are consistent with secondary mantle upwellings portrayed in numerical models of a mantle plume beneath a craton with a deep lithospheric keel within a regional N-S compressional regime. Early, regional ca. N-S faults in the W Superior were reactivated as dilatational antithetic (secondary Riedel/R') sinistral shears during dextral transpression and as extensional fractures and/or normal faults during N-S shortening. The Kapuskasing structural zone or uplift likely represents Proterozoic reactivation of a similar deep transverse structure. Preservation of discrete faults in the deep crust beneath zones of distributed Neoarchean dextral transcurrent to transpressional shear zones in the present-day upper crust suggests a 'millefeuille' lithospheric strength profile, with competent SCLM, mid- to deep, and upper crustal layers. Mechanically strong deep crustal felsic and mafic granulite layers are attributed to dehydration and melt extraction. Intra-crustal decoupling along a ductile décollement in the W Superior led to the preservation of early-formed deep structures that acted as conduits for magma transport into the overlying crust and focussed hydrothermal fluid flow during regional deformation. Increase in the thickness of semi-brittle layers in the lower crust during regional metamorphism would result in an increase in fracturing and faulting in the lower crust, facilitating hydrothermal and carbonic fluid flow in pathways linking SCLM to the upper crust, a factor explaining the late timing for most orogenic Au. Results provide an important new dataset for regional prospectively mapping, especially with machine learning, and exploration targeting for Au and Ni-Cr-Cu-PGE mineralization. Results also furnish evidence for parautochthonous development of the S Superior Province during plume-related rifting and cannot be explained by conventional subduction and arc-accretion models.
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