Relevant bibliographies by topics / Fractures (geologic)

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Academic literature on the topic 'Fractures (geologic)'

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

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Journal articles on the topic "Fractures (geologic)"

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Cui, Xiaoqin, Edward S. Krebes, and Laurence R. Lines. "Seismic inversion for geologic fractures and fractured media." GEOPHYSICS 82, no. 5 (2017): C145—C161. http://dx.doi.org/10.1190/geo2016-0123.1.

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Amplitude variation with offset (AVO) inversion attempts to use the available surface seismic data to estimate the density, P-wave velocity, and S-wave velocity of the earth model. Under linear slip interface theory, synthetic seismograms for models with fractures prove that fractures are also reflection generators. Consequently, observed reflections are not necessarily due to lithologic variations only, but they could be due in part to the effect of fractures. To obtain approximate equations for AVO inversion for fractured media, denoted by AVO with fracture (AVOF), we derived new equations for PP-wave reflection and transmission coefficients that are based on nonwelded contact boundary conditions. In particular, along with the fracture compliances, azimuth has also been taken into account in the equations because the fractures can have any orientation. The new approximate AVOF equations for a horizontally fractured medium with impedance contrast are developed by simplifying the equations for the new PP-wave reflection and transmission coefficients. In the new approximate AVOF equations, the reflection coefficients are divided into a welded contact part (a conventional impedance contrast part) and a nonwelded contact part (a fracture part). This makes the equations flexible enough to separately invert for the rock properties of the fracture and the background medium in the case of a fractured medium with impedance contrast. The new approximate AVOF equations state that fractures could cause the seismic reflectivity to be frequency dependent, and that the fractures not only influence the wave amplitude but also change the wave phase. The linear least-squares and nonlinear conjugate gradient inversion algorithms are applied to estimate the elastic reflectivity using the new approximate AVOF equations. The inverted results for seismic data for a horizontally fractured medium with impedance contrast are evaluated to find a more accurate delineation of the subsurface rock properties.
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Tsoflias, Georgios P., Jean‐Paul Van Gestel, Paul L. Stoffa, Donald D. Blankenship, and Mrinal Sen. "Vertical fracture detection by exploiting the polarization properties of ground‐penetrating radar signals." GEOPHYSICS 69, no. 3 (2004): 803–10. http://dx.doi.org/10.1190/1.1759466.

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Vertically oriented thin fractures are not always detected by conventional single‐polarization reflection profiling ground‐penetrating radar (GPR) techniques. We study the polarization properties of EM wavefields and suggest multipolarization acquisition surveying to detect the location and azimuth of vertically oriented fractures. We employ analytical solutions, 3D finite‐difference time‐domain modeling, and field measurements of multipolarization GPR data to investigate EM wave transmission through fractured geologic formations. For surface‐based multipolarization GPR measurements across vertical fractures, we observe a phase lead when the incident electric‐field component is oriented perpendicular to the plane of the fracture. This observation is consistent for nonmagnetic geologic environments and allows the determination of vertical fracture location and azimuth based on the presence of a phase difference and a phase lead relationship between varying polarization GPR data.
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Choo, Jinhyun, and Fan Fei. "Phase-field modeling of geologic fracture incorporating pressure-dependence and frictional contact." E3S Web of Conferences 205 (2020): 03004. http://dx.doi.org/10.1051/e3sconf/202020503004.

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Geologic fractures such as joints and faults are central to many problems in energy geotechnics. Notable examples include hydraulic fracturing, injection-induced earthquakes, and geologic carbon storage. Nevertheless, our current capabilities for simulating the development and evolution of geologic fractures in these problems are still insufficient in terms of efficiency and accuracy. Recently, phase-field modeling has emerged as an efficient numerical method for fracture simulation which does not require any algorithm for tracking the geometry of fracture. However, existing phase-field models of fracture neglected two distinct characteristics of geologic fractures, namely, the pressure-dependence and frictional contact. To overcome these limitations, new phase-field models have been developed and described in this paper. The new phase-field models are demonstrably capable of simulating pressure-dependent, frictional fractures propagating in arbitrary directions, which is a notoriously challenging task.
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Sliz, Krzysztof (Kris), and Saleh Al-Dossary. "Seismic attributes and kinematic azimuthal analysis for fracture and stress detection in complex geologic settings." Interpretation 2, no. 1 (2014): SA67—SA75. http://dx.doi.org/10.1190/int-2013-0082.1.

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Fractured rocks can exhibit good reservoir properties and provide high-permeability passages for hydrocarbons. Understanding fracture and stress systems is a key element in successful horizontal drilling and fracking for unconventional reservoir exploration. As a result, there is growing interest in methods that can estimate fracture orientation, density, and style. However, fracture detection using surface seismic data is challenging, and the results are usually ambiguous. Each method has its own strengths and weaknesses and responds to fractures and compressional stress in different ways. A major uncertainty in fracture analysis based on azimuthally variant seismic velocities is caused by interference from structural effects, localized small-scale velocity anomalies, and directional stress. They can induce azimuthal variation in velocity, which can mask the influence on traveltimes caused by the fractures. To overcome these challenges, we focused on a fracture and compressional stress detection methodology using 3D scanning of azimuthally dependent residual moveout volumes constrained by fracture-sensitive seismic attributes. Our workflow was successfully applied to wide-azimuth, highfold land seismic data acquired over a fractured formation in the northern part of Saudi Arabia, where we were able to map 3D zones with a high probability of fractures and differentiate them from areas with higher compressional stress.
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Gardner, W. Payton, Stephen J. Bauer, and Scott Broome. "Investigating Fracture Network Deformation Using Noble Gas Release." Geofluids 2021 (May 19, 2021): 1–16. http://dx.doi.org/10.1155/2021/6697819.

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We investigate deformation mechanics of fracture networks in unsaturated fractured rocks from subsurface conventional detonation using dynamic noble gas measurements and changes in air permeability. We dynamically measured the noble gas isotopic composition and helium exhalation of downhole gas before and after a large subsurface conventional detonation. These noble gas measurements were combined with measurements of the subsurface permeability field from 64 discrete sampling intervals before and after the detonation and subsurface mapping of fractures in borehole walls before well completion. We saw no observable increase in radiogenic noble gas release from either an isotopic composition or a helium exhalation point of view. Large increases in permeability were observed in 13 of 64 discrete sampling intervals. Of the sampling intervals which saw large increases in flow, only two locations did not have preexisting fractures mapped at the site. Given the lack of noble gas release and a clear increase in permeability, we infer that most of the strain accommodation of the fractured media occurred along previously existing fractures, rather than the creation of new fractures, even for a high strain rate event. These results have significant implications for how we conceptualize the deformation of rocks with fracture networks above the percolation threshold, with application to a variety of geologic and geological engineering problems.
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Selvadurai, A. P. S., A. P. Suvorov, and P. A. Selvadurai. "Thermo-hydro-mechanical processes in fractured rock formations during a glacial advance." Geoscientific Model Development 8, no. 7 (2015): 2167–85. http://dx.doi.org/10.5194/gmd-8-2167-2015.

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Abstract. The paper examines the coupled thermo-hydro-mechanical (THM) processes that develop in a fractured rock region within a fluid-saturated rock mass due to loads imposed by an advancing glacier. This scenario needs to be examined in order to assess the suitability of potential sites for the location of deep geologic repositories for the storage of high-level nuclear waste. The THM processes are examined using a computational multiphysics approach that takes into account thermo-poroelasticity of the intact geological formation and the presence of a system of sessile but hydraulically interacting fractures (fracture zones). The modelling considers coupled thermo-hydro-mechanical effects in both the intact rock and the fracture zones due to contact normal stresses and fluid pressure at the base of the advancing glacier. Computational modelling provides an assessment of the role of fractures in modifying the pore pressure generation within the entire rock mass.
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Selvadurai, A. P. S., A. P. Suvorov, and P. A. Selvadurai. "Thermo-hydro-mechanical processes in fractured rock formations during glacial advance." Geoscientific Model Development Discussions 7, no. 6 (2014): 7351–94. http://dx.doi.org/10.5194/gmdd-7-7351-2014.

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Abstract. The paper examines the coupled thermo-hydro-mechanical (THM) processes that develop in a fractured rock region within a fluid-saturated rock mass due to loads imposed by an advancing glacier. This scenario needs to be examined in order to assess the suitability of potential sites for the location of deep geologic repositories for the storage of high-level nuclear waste. The THM processes are examined using a computational multiphysics approach that takes into account thermo-poroelasticity of the intact geological formation and the presence of a system of sessile but hydraulically interacting fractures (fracture zones). The modeling considers coupled thermo-hydro-mechanical effects in both the intact rock and the fracture zones due to contact normal stresses and fluid pressure at the base of the advancing glacier. Computational modelling provides an assessment of the role of fractures that can modify the pore pressure generation within the entire rock mass.
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Huang, Jixiang, Joseph P. Morris, Pengcheng Fu, Randolph R. Settgast, Christopher S. Sherman, and Frederick J. Ryerson. "Hydraulic-Fracture-Height Growth Under the Combined Influence of Stress Barriers and Natural Fractures." SPE Journal 24, no. 01 (2018): 302–18. http://dx.doi.org/10.2118/189861-pa.

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Summary A fully coupled finite-element/finite-volume code is used to model 3D hydraulically driven fractures under the influence of strong vertical variations in closure stress interacting with natural fractures. Previously unknown 3D interaction mechanisms on fracture-height growth are revealed. Slipping of a natural fracture, triggered by elevated fluid pressure from an intersecting hydraulic fracture, can induce both increases and decreases of normal stress in the minimum-horizontal-stress direction, toward the center and tip of the natural fracture, respectively. Consequently, natural fractures are expected to be able to both encourage and inhibit the progress of hydraulic fractures propagating through stress barriers, depending on the relative locations between the intersecting fractures. Once the hydraulic fracture propagates above the stress barrier through the weakened segment near a favorably located natural fracture, a configuration consisting of two opposing fractures cuts the stress barrier from above and below. The fluid pressure required to break the stress barrier under such opposing-fracture configurations is substantially lower than that required by a fracture penetrating the same barrier from one side. Sensitivity studies of geologic conditions and operational parameters have also been performed to explore the feasibility of controlled fracture height. The interactions between hydraulic fractures, natural fractures, and geologic factors such as stress barriers in three dimensions are shown to be much more complex than in two dimensions. Although it is impossible to exhaust all the possible configurations, the ability of a 3D, fully coupled numerical model to naturally capture these processes is well-demonstrated.
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Theune, Ulrich, Dean Rokosh, Mauricio D. Sacchi, and Douglas R. Schmitt. "Mapping fractures with GPR: A case study from Turtle Mountain." GEOPHYSICS 71, no. 5 (2006): B139—B150. http://dx.doi.org/10.1190/1.2335515.

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Ground-penetrating radar (GPR) surveys were acquired of rocks on the highly fractured summit of Turtle Mountain in Canada. In 1903 a disastrous rock slide occurred at Turtle Mountain and it still poses a geologic hazard. Dips, shapes, and penetration depths of fractures are important parameters in slope-stability analysis. Determination of fracture orientation at Turtle Mountain has been based mostly on areal geologic mapping and, most recently, on data collected from boreholes. The purpose of GPR surveys was to test, confirm, and extend information about fractures and bedding planes. Data acquisition was complicated by the rough terrain; because slopes are steep and uneven. This also complicated analysis of the data. Measurement of in situ velocity — an important value for migration — was impossible. Instead, data were migrated with different velocities and data results were chosen that were considered to be reasonable. Analysis and interpretation of the data, resulted in confirmation and extension of the a priori information on orientations of fractures and bedding planes at Turtle Mountain. Despite the rough terrain and highly fractured rock mass, GPR surveys provide reliable information about the shapes and density of fractures — information important for slope-stability evaluation. The most reliable migration results obtained for velocities were considerably less than the standard velocities recorded for limestone, the dominant lithofacies at Turtle Mountain. We interpret this observation as an indicator of water within the rock. However, thorough investigation of this conclusion remains a project for future work.
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Whitaker, Amy, C. Shah Kabir, and Wayne Narr. "An Integrated Geologic and Engineering Assessment of Fracture-Flow Potential in the Ratawi Reservoir of the Wafra Field, Partitioned Neutral Zone." SPE Reservoir Evaluation & Engineering 11, no. 06 (2008): 1071–81. http://dx.doi.org/10.2118/106994-pa.

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Summary The extent to which fractures affect fluid pathways is a vital component of understanding and modeling fluid flow in any reservoir. We examined the Wafra Ratawi grainstone for which production extending for 50 years, including recent horizontal drilling, has provided some clues about fractures, but their exact locations, intensity, and overall effect have been elusive. In this study, we find that a limited number of total fractures affect production characteristics of the Ratawi reservoir. Although fractures occur throughout the Wafra field, fracture-influenced reservoir behavior is confined to the periphery of the field where the matrix permeability is low. This work suggests that for the largest part of the field, explicit fractures are not necessary in the next-generation Earth and flow-simulation models. The geologic fracture assessment included seismic fault mapping and fracture interpretation of image logs and cores. Fracture trends are in the northeast and southwest quadrants, and fractures are mineralized toward the south and west of the field. Pressure-falloff tests on some peripheral injectors indicate partial barriers, and most of these wells lie on seismic-scale faults in the reservoir, suggesting partial sealing. A few wells show fractured-reservoir production characteristics, and rate-transient analysis on a few producers indicates localized dual-porosity behavior. Producers proximal to dual-porosity wells display single-porosity behavior, however, to attest to the notion of localized fracture response. The spatially restricted fracture-flow characteristics appear to correlate with fracture or vug zones in a low-permeability reservoir. Presence of fracture-flow behavior was tested by constructing the so-called flow-capacity index (FCI), the ratio of khwell (well test-derived value) to khmatrix (core-derived property). Data from 80 wells showed khmatrix to be consistently higher than khwell, a relationship that suggests insignificant fracture production in these wells. Introduction The Wafra field is in the Partitioned Neutral Zone (PNZ) between Kuwait and Saudi Arabia, as shown in Fig. 1. The field has been producing since the 1950s and has seen renewed drilling activity since the late 1990s, including horizontal drilling and implementation of peripheral water injection (Davis and Habib 1999). The Lower Cretaceous Ratawi formation contains the most reserves of the producing intervals at Wafra. The Ratawi oolite (a misnomer--it is a grainstone) reservoir has variable porosity (5 to 35%) and permeability that ranges from tens to hundreds of md (Longacre and Ginger 1988). The main Wafra structure is a gentle (i.e., interlimb angle >170°), doubly plunging anticline trending north-northwest to south-southeast, which culminates near its northern end. The East Wafra spur is a north-trending branch that extends from the center of the main Wafra structure. As seen in Fig. 1, relief on the Main Wafra structure exceeds that on East Wafra. The Ratawi oolite in the Wafra field has been studied at length, and various authors have reported geologic and engineering elements, leading to reservoir characterization and understanding of reservoir performance. Geologic studies are those of Waite et al. (2000) and Sibley et al. (1997). In contrast, Davis and Habib (1999) presented implementation of peripheral water injection, whereas Chawathé et al. (2006) discussed realignment of injection pattern owing to lack of pressure support in the reservoir interior. Previous studies considered the reservoir to behave like a single-porosity system. But recent image-log fracture interpretations indicate high fracture densities, suggesting that the implementation of a dual-porosity model may be necessary because the high impact of fractures during field development has been recognized in some Middle East reservoirs for more than 50 years (Daniel 1954). Static and dynamic data are required to characterize fracture reservoir behavior accurately (Narr et al. 2006). Geologic description of the fracture system, by use of cores, borehole images, seismic data, and well logs, does not in itself determine whether fractures affect reservoir behavior. While seismic and some image logs were available to locate fractures in the Wafra Ratawi reservoir, no dynamic testing with the specific objective of understanding fracture impact has occurred. So, to determine whether fractures influence oil productivity significantly, we used diagnostic analyses of production data and well tests of available injectors. The assessment of fracture effects in the Ratawi reservoir will be used to guide the next generation of geologic and flow-simulation models. Dynamic data involving pressure and rate have the potential to reveal the influence of open fractures in production performance. Unfortunately, pressure-transient testing on single wells does not always provide conclusive evidence about the presence of fractures with the characteristic dual-porosity dip on the pressure-derivative signature (Bourdet et al. 1989). That is because a correct mixture of matrix/fracture storativity must be present for the characteristic signature to appear (Serra et al. 1983). In practice, interference testing (Beliveau 1989) between wells appears to provide more-definitive clues about interwell connectivity, leading to inference about fractures. In contrast to pressure-transient testing, rate-transient analysis offers the potential to provide the same information without dedicated testing. In this field, all wells are currently on submersible pumps. Consequently, the pump-intake pressure and measured rate provided the necessary data for pressure/rate convolution or rate-transient analysis. We provide the Ratawi-reservoir case study primarily as an example of the integration of diverse geologic and engineering data to develop an assessment of fracture influence on reservoir behavior. It illustrates the use of production-data diagnostic tests to determine fracture influence in the absence of targeted fracture-analysis testing. The workflow can be applied to similar static/dynamic problems, such as fault-transmissivity determination. Secondly, this analysis illustrates the process of deciding that fractures, although present throughout the reservoir, may not lead to widespread fractured-reservoir characteristics (e.g., Allan and Sun 2003).
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Dissertations / Theses on the topic "Fractures (geologic)"

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Oxenstierna, Johan. "Remote Sensing and Statistical Analysis of Fracture Populations Around Lake Thingvallavatn, SW Iceland." Thesis, Uppsala universitet, Institutionen för geovetenskaper, 2012. http://urn.kb.se/resolve?urn=urn:nbn:se:uu:diva-182201.

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This study aims at a description and statistical analysis of tectonic and magmatic fractures in the Western Volcanic Zone (WVZ) on Iceland. Two fracture populations are studied with respect to their distance to the Hengill volcano: The southern area is between 0-10 kilometers from the volcano and the northern area is between 16-25 kilometers from the volcano. The description and analysis of fractures is carried out separately for the two areas as well as for the two areas together to test different mapping procedures, statistical methods and the influence of the volcano on the properties of the fractures. There are various reasons for considering this an important study: Firstly, this is not an extensively researched field and there are many unanswered methodological questions on how to map and describe the fractures. In this study, problems such as how maps are stitched and georeferenced, how fractures are divided into segments and mapped in respect to topography, are discussed. The potential errors caused by these methodological problems are concluded to be large enough to significantly affect statistical tests analyzing fracture populations. In the analysis part, the properties of the fracture populations are studied using Kolmogorov Smirnov and χ 2 goodness-of-fit tests, scatter-plots, simple count and ratios among other methods. It was found that the fracture populations follow distributions that are not easily defined, but that they are of the same and quantifiable type. With more data their common distribution could therefore be modeled, and the factor by which the Hengill volcano affects the strike of fractures per distance unit from the volcano could be calculated. It was also found that magmatic fractures are formed in a similar, but not necessarily the same stress-field as tectonic fractures. Therefore change in magma pressure might change the local stress regime around magmatic fractures, affecting their strike.
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Reynolds, David A. "Multiphase flow and transport in fractured geologic environments." Thesis, National Library of Canada = Bibliothèque nationale du Canada, 2001. http://www.collectionscanada.ca/obj/s4/f2/dsk3/ftp04/NQ63448.pdf.

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Weatherington-Rice, Julie Bishop Paynter. "Fracture occurrence and ground water pollution potential in Ohio's glacial and lacustrine deposits: a soils, geologic, and educational perspective." The Ohio State University, 2003. http://rave.ohiolink.edu/etdc/view?acc_num=osu1072118096.

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Annewandter, Robert. "Discrete fracture and matrix simulation of C02-brine migration, hysteresis effect and capillary trapping in fractured geological formations." Thesis, Heriot-Watt University, 2015. http://hdl.handle.net/10399/2945.

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Injection of supercritical CO2 allows us to sequester an important component of the greenhouse gases in the subsurface to reduce emissions of CO2 in the energy sector. In light of global environmental change, it is of utmost importance to reliably predict the fate and containment of injected CO2 at geological time scales. Therefore, modelling of the CO2 plume migration and its containment within geological carbon storage repositories helps to uncover and understand challenges arising during injection and post-injection phase. Discrete fracture and matrix (DFM) simulations have emerged as a powerful technology to analyse the fundamental flow and transport properties in naturally fractured reservoirs and bridge gaps between geosciences and reservoir engineering: they help to validate upscaling workflows, improve the analysis of pressure transients from welltests, and allow to explore how uncertainties in fracture network properties impact hydrocarbon recovery. The key difference between DFM simulations and traditional dualporosity approaches is that the structurally complex fracture geometries are explicitly discretised as 2D surfaces in a 3D reservoir model, hence provides a more geologically realistic representation of the fracture patterns and rock matrix as compared to dualporosity models. Here I extend the DFM simulation workflow to account for capillary trapping of CO2 in fractured porous media. Fluid flow is described by a fully compositional model including an equation of state for CO2-H2O-NaCl fluids. The governing equations are discretised in space using unstructured and mixed-dimensional finite element - finite volume techniques. An Operator splitting approach is used to decouple capillary diffusion from the mass balance equation. For the first time, relative permeability hysteresis within the DFM method has been performed. I demonstrate how my new DFM approach can be applied to simulate CO2 injection and trapping of CO2 in fractured geological formations with geologically realistic fracture networks. I show how matrix diffusion and capillary forces influence the rate at which CO2 is trapped in the rock matrix.
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Ivanova, Violeta Mintcheva. "Geologic and stochastic modeling of fracture systems in rocks." Thesis, Massachusetts Institute of Technology, 1998. http://hdl.handle.net/1721.1/10025.

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Thesis (Ph. D.)--Massachusetts Institute of Technology, Dept. of Civil and Environmental Engineering, 1998.<br>Includes bibliographical references (p. 365-370).<br>by Violeta Mintcheva Ivanova.<br>Ph.D.
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Rajeh, Tawfik. "Modeling flow in fractured geologic media : upscaling and application to deep geothermal reservoirs." Thesis, Toulouse, INPT, 2019. http://www.theses.fr/2019INPT0051.

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Fractures dans les roches constituent un chemin préférentiel pour les écoulements et les transferts dans les milieux géologiques. Les roches poreuses fracturées se retrouvent dans diverses applications comme par exemple l’ingénierie pétrolière et gazière, le stockage géologique du CO2 et l’extraction d’énergie géothermique. Cette thèse de doctorat présente un ensemble d’analyses des propriétés géométriques, topologiques et hydrauliques des réseaux de fractures dans une perspective d’homogénéisation et d’application à la simulation numérique des réservoirs géothermique. La description des fractures planes en 3D, ou plus spécifiquement des réseaux de fractures discrets (dénommés « DFN » pour « Discrete Fracture Networks »), leurs propriétés statistiques et la façon de les modéliser sont étudiés. Comme la perméabilité joue un rôle essentiel dans l’écoulement et le transport dans les roches poreuses fracturées, nous avons dans un premier temps développé une procédure de changement d’échelle (upscaling) pour déterminer le tenseur de perméabilité équivalente des milieux poreux fracturé en 3D. Cette nouvelle approche est basée sur le principe de superposition, amélioré par des facteurs de connectivité déterminés tout d’abord empiriquement. Ces facteurs correctifs ont pour but de prendre en compte les propriétés de connectivité et de percolation des réseaux de fractures. Malgré son efficacité à prédire la perméabilité équivalente, la méthode proposée présente deux limitations dues essentiellement à la difficulté numérique de capter la percolation et les détails des connections des réseaux de fractures. Pour surmonter ces difficultés et pour effectuer des analyses plus fines des réseaux de fractures, un nouvel outil d’analyse des propriétés géométriques et topologiques des réseaux de fractures 3D a été développé. Dans cet outil, tous les attributs géométriques et topologiques (calcul d’intersections, longueurs de traces, amas percolant, etc.) des réseaux de fractures sont déterminés par un ensemble d’algorithmes. Ces algorithmes sont validés en détails, et leurs efficacités computationnelles sont démontrées. La finalité de ces outils algorithmiques est de donner une représentation des réseaux de fractures par graphes. Avec ces nouveaux outils, les capacités à traiter des réseaux de fractures 3D sont fortement améliorées. Ainsi, en utilisant la représentation en graphes, de nouvelles approches ont été développées concernant trois aspects des réseaux de fractures : (i) la percolation, (ii) le phénomène de groupement de fractures (Clustering) et (iii) la monté d’échelle de la perméabilité par la méthode des graphes. Un simulateur thermo-hydraulique a in fine été développé avec le code open source « OpenFoam ». L’objectif est d’appliquer les techniques de changement d’échelle développées dans cette thèse à des problèmes de simulations des réservoirs géothermiques. Un premier exemple prototype de système de deux puits d’injection-production dans un réservoir géothermique est simulé. D’autres cas sont en cours de traitement dans le cadre du projet GEOTREF ( www.geotref.com )<br>Fractures constitute major pathways for flow and transport in fractured porous rocks. These types of rocks are encountered in a wide range of applications like for example gas and petroleum engineering, CO2 sequestration and geothermal energy extraction. The present thesis presents a framework to analyze geometrical, topological and hydraulic properties of 3D planar fracture networks with focus on upscaling these properties to obtain an equivalent continuum, in view of application to simulations of geothermal reservoir exploitation. The description of fractures and discrete fracture networks (DFN), their statistical properties and their generation procedures are studied. As permeability plays a key role in flow and transport in fractured porous rocks, we have developed a fast upscaling approach for determining the equivalent permeability tensor of 3D fractured porous media. This new approach is based on the superposition principle improved by empirical connectivity factors in order to take into account the connectivity and percolation properties of the fracture network. Although efficient in predicting permeability, the proposed method presents a major limitation due mainly to the difficulty in assessing the percolation and connectivity properties of the network. To overcome these limitations and for further insightful analyses of DFN composed of planar fractures, an original framework of geometrical and topological analysis of 3D fracture networks has been developed. In this framework, all the geometrical and topological attributes (intersections, areas, trace lengths, clusters, percolating clusters, etc.) of a DFN are explicitly calculated by a set of algorithms. These algorithms are validated in detail by comparison to commercial softwares, and their computational efficiency is highlighted. The final purpose of this framework is to give a graph representation of the DFN. Given the newly developed tools, our capabilities of treating fracture networks have drastically increased. Hence, using a graph representation of the DFN, new approaches have been developed concerning two main issues with fracture networks: (i) percolation, (ii) clustering phenomenon (i.e., the formation of clusters by groups of fractures) and (iii) permeability upscaling. A large scale thermo-hydraulic simulator has therefore been developed with the finite volume open source code “OpenFoam”. The purpose is to apply the upscaling techniques to large scale reservoir configurations with a full coupling with heat transfer. A typical example of injectionproduction wells in a 3D geothermal reservoir is presented, and other cases are being developed within the GEOTREF project ( www.geotref.com )
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Lubbe, Rudi. "A field and laboratory investigation of the compliance of fractured rock." Thesis, University of Oxford, 2005. http://ora.ox.ac.uk/objects/uuid:699841b5-3f5f-4b04-8123-ec8912bdaf4a.

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Compressional and shear wave velocity and attenuation measurements were obtained in the laboratory from 50 mm diameter, cylindrical, limestone core samples over a confining pressure range of 5 – 60 MPa. Normal and tangential fracture compliance values, as a function of confining pressure, were calculated for a single fracture cut perpendicular to the long axis of the core. The ratio of the normal to tangential compliance was approximately 0.4 and was independent of the applied stress. Values of normal and tangential fracture compliance calculated were of the order 10<sup>-14</sup> m/Pa, and decreased with an increase in confining pressure. Both Q<sup>-1</sup></sup><sub>P</sub> and Q<sup>-1</sup></sup><sub>S</sub>1/Qs were shown to be small for these samples. A borehole test site was constructed in a Carboniferous limestone quarry, at Tytherington, situated north of Bristol, UK. This quarry was chosen because the rock type was fairly homogeneous and the fractures could be mapped in the quarry walls as well as down three, 40 m vertical boreholes drilled in-line in the quarry floor. Wireline logs were obtained in all the holes and a seismic crosshole survey was carried out between the two outermost boreholes. An estimate of in-situ normal fracture compliance, Z<sub>N</sub>, was obtained from the log and crosshole data, in 4 different ways, using effective medium theories as well as the displacement discontinuity theory. An additional estimate of Z<sub>N</sub> was obtained from a separate borehole test site constructed in fractured Devonian meta-sediments at Reskajeage, Cornwall, UK. These fractures were much larger in size than those observed at Tytherington quarry. From the above field and laboratory measurements, fracture compliance was shown to increase approximately linearly with the size of the fractures. In addition, a study of crosshole seismic attenuation was performed at Tytherington quarry. Q was found to be frequency dependent. This frequency dependence was interpreted as being due to scattering rather than intrinsic attenuation.
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Meyer, Thomas 1970. "Geologic stochastic modeling of rock fracture systems related to crustal faults." Thesis, Massachusetts Institute of Technology, 1999. http://hdl.handle.net/1721.1/9317.

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Thesis (S.M.)--Massachusetts Institute of Technology, Dept. of Civil and Environmental Engineering, 1999.<br>Includes bibliographical references (p. 223-225).<br>In this study, the capabilities of the MIT three-dimensional geologic stochastic fracture model were extended so that fracture systems related to crustal faulting can be simulated. As presented here, the model comprises four stochastic processes: 1) a homogeneous, anisotropic Poisson process to model the orientation of the potential fracture planes according to an orientation distribution; 2) a homogeneous Poisson line process that tessellates the fracture planes and associates the polygons with fractured and intact rock; 3) a zone marking process that retains or discards the polygons according to their location in the modeling volume; 4) a process that translates and rotates the polygons from their original position in order to accommodate local geologic features. This research enhanced the capabilities of the model by introducing various ways of defining the zones in the zone marking process, and by developing new procedures to analyze the connectivity of the fracture systems. Two case studies of fracture systems generation were addressed. The first one discussed the formation of fault zones in igneous rock. It demonstrated that fracture sets with different properties can be generated in different, sharply defined zones of the same modeling volume. The second case analyzed the fracture systems in the bedrock underlying the Aberjona Valley. It showed that a correct treatment of field data could lead to reliable input parameters for the model, and therefore to reliable properties of the simulated fracture systems, in terms of fracture intensity, fracture size, fracture spacing along boreholes and fracture trace length on outcrops. Connectivity assessment of the simulated fracture systems in the bedrock underlying the Aberjona Valley was performed through analysis of the isolated clusters of interconnected fractures (fracture sub-networks). The horizontal extent of the largest sub-networks appeared to be limited to 9 meters in direction East-West and 11 meters in direction North-South, regardless of the size of the modeling volume. The extent in the vertical direction was not limited. The geometry of the sub-networks seems therefore to limit horizontal fracture flow over long distances, while providing significant storage capacity. Simulations of the fracture flow run with a finite element model developed at ETHZ confirmed the geometry of the phreatic surface as observed in field pumping tests. They also pointed out the role of large discontinuities in fracture flow and the need to model large volumes of rock to account for it.<br>by Thomas Meyer.<br>S.M.
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Hekmatnejad, Amin. "Geostatistical modeling of discrete fracture networks for geomechanical applications in heterogeneous fractured media based on the cox-boolean model." Tesis, Universidad de Chile, 2018. http://repositorio.uchile.cl/handle/2250/167753.

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Doctor en Ingeniería de Minas<br>La caracterización de fracturas es crítica en minería a cielo abierto y subterránea, así como en ingeniería geológica e ingeniería de petróleo, para comprender las propiedades mecánicas e hidráulicas del macizo rocoso. Dado que se observa una fracción muy pequeña de las fracturas en un área de estudio, no es aconsejable un modelo determinístico de la red de fracturas y, a menudo, es preferible un modelo estocástico. Esta tesis se centra en el llamado modelo Cox-Booleano de discos planos para describir redes de fracturas discretas, que se basa en la definición de un proceso puntual de Cox que representa los centros de fracturas, así como en una distribución de las orientaciones y de los diámetros de fracturas. El problema específico abordado es la inferencia de los parámetros del modelo, basada en información de muestreo 1D o 2D que se origina a partir de sondajes, observaciones en líneas o bidimensionales. Las soluciones actuales al problema de inferencia suelen ser aproximadas o incipientes, especialmente en lo que se refiere al potencial del proceso de Cox subyacente, que consiste en un campo aleatorio que modela el número promedio de centros de fracturas por unidad de volumen del macizo rocoso. Se desarrollan tres métodos para modelar los parámetros de un modelo Cox-Booleano. El primero se centra en la estimación de la distribución de diámetros de fracturas en función de la distribución de longitudes de trazas determinadas a partir de observaciones areales. El segundo método aborda el problema de predecir espacialmente la intensidad de fracturas (P32) y cuantificar la incertidumbre en los valores verdaderos de P32, utilizando la información de las discontinuidades observadas a lo largo de sondajes. El tercer método permite inferir la distribución del potencial en base a la intensidad de fracturas como una variable auxiliar y a una identidad general entre las distribuciones de diámetros de fracturas, de la intensidad de fracturas y del campo potencial sobre un soporte de bloque grande. Las herramientas y métodos propuestos se aplican a estudios de casos sintéticos y reales para demostrar su aplicabilidad. El conocimiento de los parámetros del modelo abre el camino para simular el DFN en el espacio y condicionar la simulación a datos observados.
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Shackleton, John Ryan. "Numerical Modeling of Fracturing in Non-Cylindrical Folds: Case Studies in Fracture Prediction Using Structural Restoration." Amherst, Mass. : University of Massachusetts Amherst, 2009. http://scholarworks.umass.edu/open_access_dissertations/82/.

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Books on the topic "Fractures (geologic)"

1

Adler, Pierre M. Fractures and fracture networks. Kluwer, 1999.

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Geologic analysis of naturally fractured reservoirs. 2nd ed. Gulf Professional Pub., 2001.

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Nelson, Ronald A. Geologic analysis of naturally fractured reservoirs. Gulf Pub. Co., Book Division, 1985.

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Philipp, Sonja L., and Valerio Acocella, eds. Rock fractures in geological processes. Göttingen University Press, 2013. http://dx.doi.org/10.17875/gup2013-231.

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L, Dean Stuart, Ward B. J, and American Association of Petroleum Geologists., eds. Fractured core analysis: Interpretation, logging, and use of natural and induced fractures in core. American Association of Petroleum Geologists, 1990.

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Narr, Wayne. Naturally fractured reservoir characterization. Society of Petroleum Engineers, 2006.

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Kunkel, J. R. Comparative evaluation of selected continuum and discrete-fracture models: Emphasis on dispersivity calculations for application to fractured geologic media, creston study area, eastern Washington. Division of Engineering, Office of Nuclear Regulatory Research, U.S. Nuclear Regulatory Commission, 1988.

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Kunkel, J. R. Comparative evaluation of selected continuum and discrete-fracture models: Emphasis on dispersivity calculations for application to fractured geologic media, creston study area, eastern Washington. Division of Engineering, Office of Nuclear Regulatory Research, U.S. Nuclear Regulatory Commission, 1988.

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Kunkel, J. R. Comparative evaluation of selected continuum and discrete-fracture models: Emphasis on dispersivity calculations for application to fractured geologic media, creston study area, eastern Washington. Division of Engineering, Office of Nuclear Regulatory Research, U.S. Nuclear Regulatory Commission, 1988.

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Vietnam) International Scientific Conference "Fractured Basement Reservoir" (2nd 2008 Vũng Tàu. Fractured basement reservoir: PetroVietnam 2008. Science and Technics Pub. House, 2008.

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Book chapters on the topic "Fractures (geologic)"

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Bryant, Kathryn A., and Bobak Karimi. "Recognizing Patterns in Geospatial Data Using Persistent Homology: A Study of Geologic Fractures." In Geospatial Data Science Techniques and Applications. CRC Press, 2017. http://dx.doi.org/10.1201/9781315228396-6.

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Cui, Xiaoqin, Laurence Lines, Edward Stephen Krebes, and Suping Peng. "Geological Fractures and Geophysical Assumptions." In Seismic Forward Modeling of Fractures and Fractured Medium Inversion. Springer Singapore, 2017. http://dx.doi.org/10.1007/978-981-10-3584-5_2.

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Park, R. G. "Faults and fractures." In Foundations of Structural Geology. Springer Netherlands, 1989. http://dx.doi.org/10.1007/978-94-011-6576-1_1.

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Luthi, Stefan M. "Fractured Reservoir Analysis." In Geological Well Logs. Springer Berlin Heidelberg, 2001. http://dx.doi.org/10.1007/978-3-662-04627-2_15.

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Clayton, J. D. "Deformation, fracture, and fragmentation in brittle geologic solids." In IUTAM Symposium on Dynamic Fracture and Fragmentation. Springer Netherlands, 2009. http://dx.doi.org/10.1007/978-90-481-9760-6_30.

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Fitts, Jeffrey P., and Catherine A. Peters. "13. Caprock Fracture Dissolution and C02 Leakage." In Geochemistry of Geologic CO2 Sequestration, edited by Donald J. DePaolo, David R. Cole, Alexandra Navrotsky, and Ian C. Bourg. De Gruyter, 2013. http://dx.doi.org/10.1515/9781501508073-015.

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Frizon de Lamotte, Dominique, Pascale Leturmy, Pauline Souloumiac, and Adrien Frizon de Lamotte. "When strata fracture." In Geological Objects and Structures in 3D. CRC Press, 2020. http://dx.doi.org/10.1201/9781003047230-3.

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Bayly, Brian. "Concurrent Fracture and Flow." In Mechanics in Structural Geology. Springer US, 1992. http://dx.doi.org/10.1007/978-1-4613-9166-1_7.

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Hireche, Saad, Azzedine Bouzenoune, and Djelel Bouti. "Fracture Properties in Naturally Fractured Carbonate Reservoir (Gourigueur Eocene Syncline, North-Eastern Algeria)." In The Structural Geology Contribution to the Africa-Eurasia Geology: Basement and Reservoir Structure, Ore Mineralisation and Tectonic Modelling. Springer International Publishing, 2018. http://dx.doi.org/10.1007/978-3-030-01455-1_43.

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Dubinya, Nikita Vladislavovich, and Ilya Vladimirovich Fokin. "Critically Stressed Fractures and Their Relation to Elastic Moduli." In Springer Geology. Springer International Publishing, 2018. http://dx.doi.org/10.1007/978-3-319-77788-7_5.

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Conference papers on the topic "Fractures (geologic)"

1

Crandall, Dustin, Goodarz Ahmadi, and Grant Bromhal. "Heat Flux to Fluids Within a Rock Fracture in a Geothermal System." In ASME 2010 3rd Joint US-European Fluids Engineering Summer Meeting collocated with 8th International Conference on Nanochannels, Microchannels, and Minichannels. ASMEDC, 2010. http://dx.doi.org/10.1115/fedsm-icnmm2010-30213.

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Fractures in rocks enable the motion of fluids through the large, hot geologic formations of geothermal reservoirs. The heat transfer from the surrounding rock mass to the fluid flowing through a fracture depends on the geometry of the fracture, the fluid/solid properties, and the flow rate through the fracture. A numerical study was conducted to evaluate the changes in heat transfer to the fluid flowing through a rock fracture with changes in the flow rate. The aperture distribution of the rock fracture, originally created within Berea sandstone and imaged using a CT-scanner, is well described by a Gaussian distribution and has a mean aperture of approximately 0.6 mm. Water was used as the working fluid, enabling an evaluation of the efficiency of heat flux to the fluid along the flow path of a hot dry geothermal system. As the flow through the fracture was increased to a Reynolds number greater than 2300 the effect of channeling through large aperture regions within the fracture were observed to become increasingly important. For the fastest flows modeled the heat flux to the working fluids was reduced due to a shorter residence time of the fluid in the fracture. Understanding what conditions can maximize the amount of energy obtained from fractures within a hot dry geologic field can improve the operation and long-term viability of enhanced geothermal systems.
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Crandall, Dustin, Grant Bromhal, and Duane H. Smith. "Conversion of a Micro-CT Scanned Rock Fracture Into a Useful Model." In ASME 2009 Fluids Engineering Division Summer Meeting. ASMEDC, 2009. http://dx.doi.org/10.1115/fedsm2009-78118.

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Within geologic reservoirs the flow of fluids through fractures is often orders of magnitude greater than through the surrounding, low-permeability rock. Because of the number and size of fractures in geological fields, reservoir-scale discrete-fracture simulators often model fluid motion through fractures as flow through narrow, parallel plates. In reality fractures within rock are narrow openings between two rough rock surfaces. In order to model the geometry of an actual fracture in rock, a ∼9 cm by 2.5 cm fracture within Berea sandstone was created and the aperture distribution was obtained with micro-Computed Tomography (CT) scans by Karpyn et al. [1]. The original scans had a volume-pixel (voxel) resolution of 27 by 27 by 32 microns. This data was up-scaled to voxels with 120 microns to a side to facilitate data transfer and for practicality of use. Using three separate reconstruction techniques, six different fracture meshes were created from this up-scaled data set, each with slightly different final geometries. Flow through each of these fracture meshes was evaluated using the finite-volume simulator FLUENT. While certain features of the fracture meshes, such as the shape of the fracture aperture distributions and overall volume of the void, remained similar between the different geometric reconstructions, the flow in different models was observed to vary dramatically. Rough fracture walls induced more tortuous flow paths and a higher resistance to flow. Natural fractures do vary in-situ, due to sidewall dissolution and mineral precipitation, smoothing and coarsening fracture walls respectively. Thus for our study the range of fracture properties was actually beneficial, allowing us to describe the flow through a range of fracture types. A compromise between capturing the geometric details within a domain of interest and a tractable computational mesh must always be addressed when flow through a physical geometry is modeled. The fine level of detail that is currently available from micro-CT scanning equipment can compound this problem. This study evaluates several methods of obtaining rational CFD meshes from a complex physical geometry, and discusses the benefits and disadvantages of the different procedures as they pertain to flow through a natural fracture in rock.
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Pawar, Gorakh, Ilija Miskovic, and Manjunath Basavarajappa. "Evaluation of Fluid Behaviour and Mixing Efficiency in Predefined Serpentine Micro-Fracture System." In ASME 2013 International Mechanical Engineering Congress and Exposition. American Society of Mechanical Engineers, 2013. http://dx.doi.org/10.1115/imece2013-65124.

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Scientific research and development in the field of microfluidics and nanofluidics technology has witnessed a rapid expansion in recent years. Microfluidic and nanofluidic systems are finding increasing application in wide spectrum of biomedical and engineering fields, including oil and gas technology. Fluid flow characterization in porous geologic media is an important factor for predicting and improving oil and gas recovery. By developing understanding about the propagation of hydraulic fracturing fluid constituents in irregular micro- and nano-structures, and their multiphase interaction with reservoir fluids (e.g. mixing of supercritical CO2 with oil or gas) we can significantly improve efficiency of the current oil and gas (O&amp;G) extraction process and reduce associated environmental impacts. In present paper, mixing of hydraulic fracturing fluid constituents in three dimensional serpentine microchannel system is simulated in CFD environment and results are used to evaluate mixing efficiency for different fracturing fluid compositions. In addition, pressure drop along the length of serpentine micro-channel is evaluated. Serpentine micro-channels considered in this study consist of periodic symmetrical and asymmetrical proppant particles, placed on both sides of the channel over the full length of the channel, to simulate realistic geometrical constraints usually seen in geological fractures. The fluid flow is characterized as a function of the proppant particle radius by varying size of adjacent proppant particles. Further, the flow is characterized by varying distance between adjacent proppant particles. Overall, this study will be primarily helpful to gain fundamental understanding of fracturing fluid mixing in micro-fractures, similar to real geologic media. In addition, this study will provide an insight into variations of fracturing fluid mixing efficiency, and pressure drop in micro-fracture systems as a function of geometry of the proppant particles at different flow rates.
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Tsoflias, Georgios, Jean‐Paul Van Gestel, Paul Stoffa, and Mrinal Sen. "Detection of vertical fractures in geologic formations using the polarization properties of ground‐penetrating radar signal." In SEG Technical Program Expanded Abstracts 1999. Society of Exploration Geophysicists, 1999. http://dx.doi.org/10.1190/1.1821082.

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Scully, Jennifer E. C., Debra L. Buczkowski, Scott D. King, et al. "GEOLOGIC MAPPING OF FRACTURES AND SECONDARY CRATER CHAINS UNCOVERS THE INTERIOR AND SURFACE EVOLUTION OF CERES." In GSA Annual Meeting in Denver, Colorado, USA - 2016. Geological Society of America, 2016. http://dx.doi.org/10.1130/abs/2016am-283508.

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Bate, Kevin, Mauricio Lane, Alexey Moiseenkov, and Sergey Nadezhdin. "Geological Model Coupled with Geomechanics Makes an Impact on Fracturing Stimulation and Field Development Strategy of a Tight Gas Formation in the Sultanate of Oman." In SPE Middle East Unconventional Resources Conference and Exhibition. SPE, 2015. http://dx.doi.org/10.2118/spe-172949-ms.

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Abstract Appraisal drilling of a recently discovered Cambrian-aged gas field in Oman is indicating that the field may have significant amounts of gas locked in a challenging deep, hot, and highly pressured reservoir environment. The low porosity and permeability values of the Amin reservoir allow the classification of the reservoir as a tight gas sand. The variability of reservoir properties, both spatially and vertically, makes it difficult to standardize perforation and fracture stimulation design which, in turn, complicates delineation of a development plan for the project. One of the difficulties relates to uncertainty in vertical propagation of hydraulic fractures. Fracture height based on evaluation of radioactive tracer logs indicates that vertical barriers to fracture propagation may relate to specific geologic zones in the reservoir. The mapping of the reservoir zones into undeveloped areas of the field would allow selection of primary and secondary production targets based on the specific physical properties of the individual zones. To assume that no barrier to fracture propagation exists between separate production units may lead to attempts to stimulate them synchronously, which would be disadvantageous for several reasons, such as premature screenouts and incomplete coverage of gas-bearing layers. Reserves booking and allocation can also be jeopardized should the fractures propagate into undesired zones.
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Romanowicz, Edwin, and Jonathan J. Kim. "RELATIONSHIP BETWEEN FRACTURES, VERTICAL WATER FLOW AND GEOLOGIC STRUCTURES ON THE DISTRIBUTION OF PFOA IN DOMESTIC WELLS, BENNINGTON, VT." In 53rd Annual GSA Northeastern Section Meeting - 2018. Geological Society of America, 2018. http://dx.doi.org/10.1130/abs/2018ne-311104.

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A. Gabry, Mohamed, Samuel A. Thabet, Emad Abdelhaliem, Ahmed Algarhy, and Maharaja Palanivel. "Ability to Use DFIT to Replace the Minifrac in Sandstone Formations for Reservoir Characterizations." In SPE 2020 Symposium Compilation. SPE, 2021. http://dx.doi.org/10.2118/201216-ms.

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Abstract One of essential parts of hydraulic fracture job design optimization in deep sandstone formations is to conduct a minifrac test using fracture fluid to identify the closure pressure for calibration of the stress profile and to calibrate the leak-off coefficient of the fracturing fluid, but the test could not provide good understanding for reservoir properties of permeability, reservoir pressure, and intensity of natural fractures. By conducting the actual DFIT (Diagnostic Fracture Injection Test) and minifrac in more than thirty wells in different formations from different fields, several leak-off behaviors are observed and several conclusions can be reached by integrating minifrac, DFIT, geologic settings information, and production data. With the experience of conducting high rate and low rate DFIT before minifrac jobs, we can conclude that there are several benefits for the DFIT by replacing the minifrac, which conventionallyusesg a polymer fracturing fluid, with a non-wall-building fluid consisting mainly of water from the operations and job design perspective, and from the post frac production perspective. DFIT with water can introduce the best methodology to detect the induced complexity that may cause hydraulic fracture job cancellation in cases of detecting high complexity value early before rig movement. Implementing DFIT in a complete hydraulic fracturing design, execution and evaluation workflow can provide a deep understanding of the fracture geometry propagation and reservoir characterization. The main disadvantages of the DFIT is that it requires a long leak-off observation period but that can be minimized in the mD range of sandstone permeability. This paper introduces DFIT in sandstone formations as a good method for integration between the geology, reservoir management, and fracture operations. The paper provides the operational and integral benefits of replacing minifrac and fracturing fluid with DFIT and water in deep sandstone formations, which provides more accurate data analysis because testing is done with same fluid. In addition, it can reduce fracture operations cost by 10%.
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Malhotra, Sahil, Tom Merrifield, Cynthia Lynch, Dave Larue, Angela Madding, and Jye Collins. "Coiled Tubing Horizontal Well Fracturing in the Low Young's Modulus, Low Permeability Belridge Diatomite: Challenges Faced and Lessons Learned." In SPE Hydraulic Fracturing Technology Conference. SPE, 2015. http://dx.doi.org/10.2118/spe-173365-ms.

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Abstract Coiled tubing fracturing has been successfully applied in multi-stage vertical well stimulation in the Belridge diatomite in the Lost Hills field. This same methodology was used to complete two northwest-trending horizontal wells drilled on the northeast flank of the Lost Hills anticlinal structure that targeted thinner higher oil-saturation strata, separated by thicker low oil-saturation intervals. The target reservoir is comprised of high porosity, low matrix permeability Opal A diatomite. The perforations were jetted by pumping sand slurry down the coiled tubing and the frac job was pumped down the annulus. The stages were isolated by setting sand plugs. Nine and twelve stages were pumped in the two wells respectively. The perforation locations for different stages were selected in areas with: 1) high resistivity and inferred high oil saturations, 2) absence of hydraulic fractures from nearby wells, 3) excellent cement bonding, and 4) low intensity of natural fractures. These assessments followed logging while drilling (LWD) gamma ray, induction resistivity and azimuthally focused resistivity (image) logs and cased-hole ultrasonic image tool (USIT) run with the aid of a tractor. The hydraulic fractures were monitored using surface tiltmeter sensors. Oil and water soluble tracers were pumped to determine the relative production contribution from the stages and fracture fluid cleanup, respectively, from the stages. All the jobs could be successfully pumped without any screen outs. Challenges were faced in setting sand plugs and isolating stages. Large fracture widths and low leak-off into the formation led to difficulty in forming sand bridges at the perforations and concentrating sand in the wellbore for the plugs. Surface tiltmeters showed excessive fracture height growth. Tracer results showed that 20-30% of the stages contributed to 50-60% of the production. Stages with higher treating pressures contributed less towards production. This could be attributed to near wellbore tortuosity in these stages. Proppant flowback was encountered in one well, and after an effective clean up the production rose. The study illustrates how integration of various aspects such as completion design, fracture pressure analysis and diagnostics combined with geologic and reservoir information can help in identifying challenges and finding potential solutions of hydraulic fracturing. The findings highlight that the technology most suitable for vertical well stimulation might not be favorable for horizontal well stimulation.
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Hughes, Mary L., C. Allen Ross, and Voncile L. Ashley. "Effect of Compressive Stress on Longitudinal Wave Speed in Cementitious Material." In ASME 2002 Pressure Vessels and Piping Conference. ASMEDC, 2002. http://dx.doi.org/10.1115/pvp2002-1156.

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The Air Force has been interested for some time in the development of computer codes that accurately predict the penetrator trajectory created when munitions are fired into concrete and geomaterial targets, as well as the resulting depth of penetration. Recent work has focused on experimental research performed to determine quasistatic, dynamic, unconfined and confined material properties for development of an elastic/viscoplastic constitutive equation. This constitutive equation has shown some promise in predicting stress and strains but lacks a consistent damage parameter to predict damage or fractures exhibited by the target material during experimental impact tests. Current damage level predictors that employ a scalar damage parameter are not sufficient to predict the directional damage or fracture that occurs in simple uniaxial compression tests of concrete and geomaterials. Tensorial or directional damage parameters coupled with constitutive relations are necessary for better understanding and accurate prediction of damage exhibited when munitions impact concrete and geomaterials. The primary objective of the study described herein was to identify, quantify and characterize damage parameters associated with certain constitutive responses of cementitious and geologic materials. To that end, longitudinal wave speed and biaxial strain data were collected simultaneously on a series of grout cubes as they were being loaded to failure in uniaxial compression. The results of these tests, and a comparison to existing related data [1, 2] are presented.
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Reports on the topic "Fractures (geologic)"

1

Martel, S. J. Geologic characterization of fractures as an aid to hydrologic modeling of the SCV block at the Stripa mine. Office of Scientific and Technical Information (OSTI), 1992. http://dx.doi.org/10.2172/7256716.

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Martel, S. J. Geologic characterization of fractures as an aid to hydrologic modeling of the SCV block at the Stripa mine. Office of Scientific and Technical Information (OSTI), 1992. http://dx.doi.org/10.2172/10179467.

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Steele, T., J. Kunkel, S. Way, and R. Koenig. Flow of groundwater and transport of contaminants through saturated fractured geologic media. Office of Scientific and Technical Information (OSTI), 1989. http://dx.doi.org/10.2172/6019097.

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Ababou, R. Approaches to large scale unsaturated flow in heterogeneous, stratified, and fractured geologic media. Office of Scientific and Technical Information (OSTI), 1991. http://dx.doi.org/10.2172/138205.

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Makedonska, Nataliia. FracMan / dfnWorks: From Geological Fracture Characterization to Multiphase Subsurface Flow and Transport Simulation. Office of Scientific and Technical Information (OSTI), 2018. http://dx.doi.org/10.2172/1479909.

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Jon E. Olson, Larry W. Lake, and Steve E. Laubach. ADVANCED TECHNOLOGY FOR PREDICTING THE FLUID FLOW ATTRIBUTES OF NATURALLY FRACTURED RESERVOIRS FROM QUANTITATIVE GEOLOGIC DATA AND MODELING. Office of Scientific and Technical Information (OSTI), 2003. http://dx.doi.org/10.2172/820623.

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Susan Nissen, Saibal Bhattacharya, W. Lynn Watney, and John Doveton. Improving Geologic and Engineering Models of Midcontinent Fracture and Karst-Modified Reservoirs Using New 3-D Seismic Attributes. Office of Scientific and Technical Information (OSTI), 2009. http://dx.doi.org/10.2172/967045.

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Eliason, J. R., and G. L. Landle. Geologic spatial analysis program users guide for digital elevation model analysis procedures for detection of crustal fracture planes. Office of Scientific and Technical Information (OSTI), 1988. http://dx.doi.org/10.2172/6274159.

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Gutierrez, Marte. Training and Research on Probabilistic Hydro-Thermo-Mechanical Modeling of Carbon Dioxide Geological Sequestration in Fractured Porous Rocks. Office of Scientific and Technical Information (OSTI), 2013. http://dx.doi.org/10.2172/1097093.

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10

Olson, Jon E., Larry W. Lake, and Steve E. Laubach. Advanced technology for predicting the fluid flow attributes of naturally fractured reservoirs from quantitative geological data and modeling. Office of Scientific and Technical Information (OSTI), 2004. http://dx.doi.org/10.2172/838717.

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