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Stephen E. Laubach - One of the best experts on this subject based on the ideXlab platform.
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Fracture Porosity creation and persistence in a basement involved laramide fold upper cretaceous frontier formation green river basin usa
Geological Magazine, 2016Co-Authors: Stephen E. Laubach, Andras Fall, Lauren K Copley, Randall Marrett, Scott J WilkinsAbstract:Fracture-hosted Porosity and quartz distribution along with crack-seal texture and fluid inclusion assemblage sequences in isolated, bridging quartz deposits show that open Fractures can persist through protracted burial and uplift in foreland basins. Fractures oriented at a high angle to current maximum compressive stress remain open and were weak mechanical discontinuities for millions of years even at great depth. Upper Cretaceous Frontier Formation sandstones in the basement-involved (Laramide) Table Rock anticline, eastern Greater Green River Basin, Wyoming sampled by two horizontal wells (cut parallel or nearly parallel to bedding and at a high angle to steeply dipping Fractures) have 41.5 m of rock in four cores at depths of 4538–4547 m. Cores intersect older E-striking Set 1 Fractures are abutted by or locally cross-cut by N-striking Set 2 Fractures. Both sets contain quartz and Porosity. Sequenced using quartz crack-seal cement texture maps, Set 1 fluid inclusion assemblage (FIA) trapping temperatures increase progressively from 140 to 165°C then decrease to c . 150°C, compatible with Fracture opening over c . 15 Ma during rapid burial followed by uplift in Eocene–Oligocene time. Set 2 opened at c . 160°C, probably near maximum burial. After a period of quiescence, Set 2 reopened at c . 5 Ma at c . 140°C, on a cooling trajectory. Intermittent Set 2 movement could reflect local basement-involved fault movement, followed after a pause by further Set 2 reactivation in the modern stress field during uplift. Interpretations are sensitive to available burial/thermal histories, which have considerable uncertainty.
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Fracture abundance and patterns in the subandean fold and thrust belt devonian huamampampa formation petroleum reservoirs and outcrops argentina and bolivia
Marine and Petroleum Geology, 2012Co-Authors: Juan Inigo, Stephen E. Laubach, John N. HookerAbstract:Abstract Opening-mode Fractures in Devonian sandstones in outcrop and in several fields in the Subandean Ranges of southern Bolivia and northern Argentina compose two Fracture sets, I and II that strike west–northwest and north–northeast, respectively. Abundant Set I Fractures are at a high angle to local Andean structural trends, and Set II is aligned with fold axes. Crosscutting relations and quartz textures in Fractures suggest that, although Set I is locally older, these sets may have opened partly contemporaneously. Sets comprise both macroscopic Fractures and more abundant, millimeter-scale microFractures . Fractures with opening displacement of less than 0.1 mm are typically sealed with quartz, but wider Fractures are lined with quartz and contain connected Fracture Porosity. MicroFractures are more abundant than macroFractures, and size distributions can be interpreted to approximate power laws. MicroFracture strain is an efficient method of quantifying Fracture abundance. Both sets record small Fracture strains of 0.00016–0.0083. In backlimbs Set I strain is higher in brittle quartz-rich sandstones. Set II strain varies markedly and is generally high in hinges and steep forelimbs of asymmetric anticlines. For individual samples, Set I–II strains in fold hinges and forelimbs are comparable, consistent with concurrent Set I–II growth. Open Fractures that could augment permeability are present both on and off structure, but microFractures document Fracture abundance that varies with structural position and sandstone quartz content that could account for variations in production outcomes.
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Modeling Fracture Porosity evolution in dolostone
Journal of Structural Geology, 2010Co-Authors: Julia F. W. Gale, R. H. Lander, Robert M. Reed, Stephen E. LaubachAbstract:Abstract Opening-mode Fractures in dolostones buried to depths of ∼1–5 km contain synkinematic dolomite cement, the amount and internal structure of which has a systematic relationship to Fracture size. Narrow Fractures ( We developed a geometric crystal growth model for synkinematic dolomite Fracture fill in Fractured dolostones, where periodic incremental Fracture-opening events are introduced with concurrent cement growth. We assumed constant temperature and supersaturation with respect to dolomite. A key assumption in the model is that rapid dolomite accumulation within bridges is governed by high cement-growth rates on repeatedly broken grain surfaces during the process of crack seal. Slower cement-growth rates occur on euhedral crystals. This assumption is made on the basis of a comparison with quartz cement growth in Fractured sandstones. Simulations with different Fracture-opening rates mimic bridge and lining cement morphologies, including characteristic rhombic shapes of dolomite bridges.
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diagenesis in Porosity evolution of opening mode Fractures middle triassic to lower jurassic la boca formation ne mexico
Tectonophysics, 2006Co-Authors: Stephen E. Laubach, Meghan E WardAbstract:Abstract Opening-mode Fractures (joints) in Middle Triassic to Lower Jurassic La Boca Formation sandstones, northeastern Mexico, have patterns of Fracture Porosity, mineral-fill structures, and size distributions not previously described from outcrop. Patterns match those found in cores from many basins. We used aperture measurements along lines of observation (scanlines), Fracture-trace maps, petrography, high-resolution scanning-electron-microscope-(SEM)-based cathodoluminescence, and fluid inclusions to characterize Fracture populations. Open Fractures are lined by quartz that precipitated while Fractures were opening, whereas sealed Fractures additionally contain calcite deposited after Fractures ceased opening. Large Fractures and arrays of contemporaneous microFractures have consistent power-law aperture-size scaling over approximately three orders of magnitude. Our results imply that open Fractures and Fracture sizes depend on diagenetic state. The interplay of Fracture mechanics and diagenetic history is a determinant on effective Porosity within Fractures and, thus, open Fracture persistence, connectivity, and fluid flow.
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coevolution of crack seal texture and Fracture Porosity in sedimentary rocks cathodoluminescence observations of regional Fractures
Journal of Structural Geology, 2004Co-Authors: Stephen E. Laubach, R. H. Lander, Robert M. Reed, Jon E Olson, Linda M BonnellAbstract:Abstract This paper examines evidence of coupled diagenetic and mechanical processes within growing Fractures in sandstones: crack-seal texture and associated, concurrently produced Fracture Porosity. Crack-seal textures in narrow mineral bridges associated with Fracture Porosity are common in regional Fractures formed at moderate to great depth (>1000–∼6000 m) in quartz-cemented sandstones that otherwise lack significant structure. Use of SEM-based cathodoluminescence systems and superposition of images collected using color filters accurately delineate crack-seal increments in Fracture-bridging quartz cement. Bridges and crack-seal texture mark competition between cement precipitation and opening rates during opening-mode Fracture growth. These structures document episodic Fracture growth that can include tens to hundreds of widening increments in Fractures having apertures of a few tens of microns to several millimeters or more. These structures are not the product of unique circumstances in burial history and fluid flow but, rather, reflect the confluence of rock-dominated geochemistry that is widespread in time and space and fracturing caused by a spectrum of loading conditions.
Naser Golsanami - One of the best experts on this subject based on the ideXlab platform.
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distinguishing Fractures from matrix pores based on the practical application of rock physics inversion and nmr data a case study from an unconventional coal reservoir in china
Journal of Natural Gas Science and Engineering, 2019Co-Authors: Naser Golsanami, Jianmeng Sun, Ying Liu, Weichao Yan, Chen Lianjun, Lishuai Jiang, Huaimin Dong, Chenglin Zong, Haiqing WangAbstract:Abstract Our main scheme in this study was distinguishing between Fracture Porosity and matrix Porosity in coalbed methane reservoirs through a novel approach which is the joint usage of NMR transverse relaxation (T2) measurements and rock physics modeling based on Levenberg-Marquardt (LM) algorithm. For this purpose, NMR T2 relaxation curves of 34 water-saturated coal samples, prepared and processed in the laboratory, were measured and the pore size distribution inside them was investigated. Subsequently, matrix and Fracture Porosity were separated based on the threshold T2 relaxation time (90–110 ms) which was achieved through our particularly designed fracturing experiments (this is different from the common T2 cutoff). The T2 measurements were performed in the laboratory using our NMR machine. After that, a rock physics scheme based on Levenberg-Marquardt algorithm was applied to independently estimate matrix Porosity and Fracture Porosity from the samples' statistic mechanical properties including compressional wave velocity (Vp), shear wave velocity (Vs), bulk modulus (K), shear modulus (G), Young's modulus (E), and Poisson's ratio (ν) which were all carefully measured in the laboratory. Afterward, both types of the abovementioned porosities were comprehensively characterized and the obtained achievements were listed. Once finished with this step, the 3D structure of the entire reservoir was extracted using the recorded data inside 32 drilled wells, and then the established models were upscaled and the unique and independent contour maps of Fracture Porosity and matrix pore Porosity were drawn over the entire reservoir area. The proposed novel approach provides the kind of information about Fractures of the media which is not obtainable with either of NMR or rock physics methods when they are used individually. This study established a novel discussion investigating application of rock physics relationships in order to determine Fracture Porosity of the coal reservoirs. The approach was used to successfully investigate and characterize pore-only Porosity and Fracture-only Porosity of a coalbed methane reservoir. According to the obtained results, joint usage of rock physics modeling and LM algorithm would be considered as a reliable technique in quick or deeper exploration of unconventional coal reservoirs.
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distinguishing Fractures from matrix pores based on the practical application of rock physics inversion and nmr data a case study from an unconventional coal reservoir in china
Journal of Natural Gas Science and Engineering, 2019Co-Authors: Naser Golsanami, Chen Lianjun, Lishuai Jiang, Huaimin Dong, Chenglin Zong, Haiqing WangAbstract:Abstract Our main scheme in this study was distinguishing between Fracture Porosity and matrix Porosity in coalbed methane reservoirs through a novel approach which is the joint usage of NMR transverse relaxation (T2) measurements and rock physics modeling based on Levenberg-Marquardt (LM) algorithm. For this purpose, NMR T2 relaxation curves of 34 water-saturated coal samples, prepared and processed in the laboratory, were measured and the pore size distribution inside them was investigated. Subsequently, matrix and Fracture Porosity were separated based on the threshold T2 relaxation time (90–110 ms) which was achieved through our particularly designed fracturing experiments (this is different from the common T2 cutoff). The T2 measurements were performed in the laboratory using our NMR machine. After that, a rock physics scheme based on Levenberg-Marquardt algorithm was applied to independently estimate matrix Porosity and Fracture Porosity from the samples' statistic mechanical properties including compressional wave velocity (Vp), shear wave velocity (Vs), bulk modulus (K), shear modulus (G), Young's modulus (E), and Poisson's ratio (ν) which were all carefully measured in the laboratory. Afterward, both types of the abovementioned porosities were comprehensively characterized and the obtained achievements were listed. Once finished with this step, the 3D structure of the entire reservoir was extracted using the recorded data inside 32 drilled wells, and then the established models were upscaled and the unique and independent contour maps of Fracture Porosity and matrix pore Porosity were drawn over the entire reservoir area. The proposed novel approach provides the kind of information about Fractures of the media which is not obtainable with either of NMR or rock physics methods when they are used individually. This study established a novel discussion investigating application of rock physics relationships in order to determine Fracture Porosity of the coal reservoirs. The approach was used to successfully investigate and characterize pore-only Porosity and Fracture-only Porosity of a coalbed methane reservoir. According to the obtained results, joint usage of rock physics modeling and LM algorithm would be considered as a reliable technique in quick or deeper exploration of unconventional coal reservoirs.
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a review on the applications of the nuclear magnetic resonance nmr technology for investigating Fractures
Journal of Applied Geophysics, 2016Co-Authors: Naser Golsanami, Jianmeng Sun, Zhiying ZhangAbstract:Abstract This review focuses on the recent applications of nuclear magnetic resonance (NMR) technology for characterizing Fractures. The paper aims to help researchers in extending the existing reservoir characterization methods (which are commonly used in conventional hydrocarbon reservoirs) for appropriate usage in unconventional resources. This is because some techniques for quantifying and qualifying Fractures have been investigated in conventional sandstone and carbonate reservoirs, but the reality for unconventional resources is that such techniques are still poorly developed. Fractures are necessary for economical production of petroleum from many low-permeability reservoirs. The characterization of Fractures by well logging technology is of great interest in the petroleum industry. The main purpose of this study is to review the characterization techniques that are developed either for identifying Fractures or distinguishing Fracture Porosity from matrix Porosity. This concept plays a leading role in providing availability of an optimized well completion program. The results of this study indicated that in terms of both sandstone and carbonate tight reservoirs, there have not been many steps taken toward the aforementioned goal up to now. Nevertheless, these steps are valuable enough to be counted on and could serve a meaningful function in treating hydrocarbon reservoirs. Because of the ongoing changes in today's petroleum industry, development of a comprehensive methodology will create greater economic benefits in unconventional reservoirs than in the conventional ones.
Haiqing Wang - One of the best experts on this subject based on the ideXlab platform.
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distinguishing Fractures from matrix pores based on the practical application of rock physics inversion and nmr data a case study from an unconventional coal reservoir in china
Journal of Natural Gas Science and Engineering, 2019Co-Authors: Naser Golsanami, Jianmeng Sun, Ying Liu, Weichao Yan, Chen Lianjun, Lishuai Jiang, Huaimin Dong, Chenglin Zong, Haiqing WangAbstract:Abstract Our main scheme in this study was distinguishing between Fracture Porosity and matrix Porosity in coalbed methane reservoirs through a novel approach which is the joint usage of NMR transverse relaxation (T2) measurements and rock physics modeling based on Levenberg-Marquardt (LM) algorithm. For this purpose, NMR T2 relaxation curves of 34 water-saturated coal samples, prepared and processed in the laboratory, were measured and the pore size distribution inside them was investigated. Subsequently, matrix and Fracture Porosity were separated based on the threshold T2 relaxation time (90–110 ms) which was achieved through our particularly designed fracturing experiments (this is different from the common T2 cutoff). The T2 measurements were performed in the laboratory using our NMR machine. After that, a rock physics scheme based on Levenberg-Marquardt algorithm was applied to independently estimate matrix Porosity and Fracture Porosity from the samples' statistic mechanical properties including compressional wave velocity (Vp), shear wave velocity (Vs), bulk modulus (K), shear modulus (G), Young's modulus (E), and Poisson's ratio (ν) which were all carefully measured in the laboratory. Afterward, both types of the abovementioned porosities were comprehensively characterized and the obtained achievements were listed. Once finished with this step, the 3D structure of the entire reservoir was extracted using the recorded data inside 32 drilled wells, and then the established models were upscaled and the unique and independent contour maps of Fracture Porosity and matrix pore Porosity were drawn over the entire reservoir area. The proposed novel approach provides the kind of information about Fractures of the media which is not obtainable with either of NMR or rock physics methods when they are used individually. This study established a novel discussion investigating application of rock physics relationships in order to determine Fracture Porosity of the coal reservoirs. The approach was used to successfully investigate and characterize pore-only Porosity and Fracture-only Porosity of a coalbed methane reservoir. According to the obtained results, joint usage of rock physics modeling and LM algorithm would be considered as a reliable technique in quick or deeper exploration of unconventional coal reservoirs.
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distinguishing Fractures from matrix pores based on the practical application of rock physics inversion and nmr data a case study from an unconventional coal reservoir in china
Journal of Natural Gas Science and Engineering, 2019Co-Authors: Naser Golsanami, Chen Lianjun, Lishuai Jiang, Huaimin Dong, Chenglin Zong, Haiqing WangAbstract:Abstract Our main scheme in this study was distinguishing between Fracture Porosity and matrix Porosity in coalbed methane reservoirs through a novel approach which is the joint usage of NMR transverse relaxation (T2) measurements and rock physics modeling based on Levenberg-Marquardt (LM) algorithm. For this purpose, NMR T2 relaxation curves of 34 water-saturated coal samples, prepared and processed in the laboratory, were measured and the pore size distribution inside them was investigated. Subsequently, matrix and Fracture Porosity were separated based on the threshold T2 relaxation time (90–110 ms) which was achieved through our particularly designed fracturing experiments (this is different from the common T2 cutoff). The T2 measurements were performed in the laboratory using our NMR machine. After that, a rock physics scheme based on Levenberg-Marquardt algorithm was applied to independently estimate matrix Porosity and Fracture Porosity from the samples' statistic mechanical properties including compressional wave velocity (Vp), shear wave velocity (Vs), bulk modulus (K), shear modulus (G), Young's modulus (E), and Poisson's ratio (ν) which were all carefully measured in the laboratory. Afterward, both types of the abovementioned porosities were comprehensively characterized and the obtained achievements were listed. Once finished with this step, the 3D structure of the entire reservoir was extracted using the recorded data inside 32 drilled wells, and then the established models were upscaled and the unique and independent contour maps of Fracture Porosity and matrix pore Porosity were drawn over the entire reservoir area. The proposed novel approach provides the kind of information about Fractures of the media which is not obtainable with either of NMR or rock physics methods when they are used individually. This study established a novel discussion investigating application of rock physics relationships in order to determine Fracture Porosity of the coal reservoirs. The approach was used to successfully investigate and characterize pore-only Porosity and Fracture-only Porosity of a coalbed methane reservoir. According to the obtained results, joint usage of rock physics modeling and LM algorithm would be considered as a reliable technique in quick or deeper exploration of unconventional coal reservoirs.
Scott J Wilkins - One of the best experts on this subject based on the ideXlab platform.
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Fracture Porosity creation and persistence in a basement involved laramide fold upper cretaceous frontier formation green river basin usa
Geological Magazine, 2016Co-Authors: Stephen E. Laubach, Andras Fall, Lauren K Copley, Randall Marrett, Scott J WilkinsAbstract:Fracture-hosted Porosity and quartz distribution along with crack-seal texture and fluid inclusion assemblage sequences in isolated, bridging quartz deposits show that open Fractures can persist through protracted burial and uplift in foreland basins. Fractures oriented at a high angle to current maximum compressive stress remain open and were weak mechanical discontinuities for millions of years even at great depth. Upper Cretaceous Frontier Formation sandstones in the basement-involved (Laramide) Table Rock anticline, eastern Greater Green River Basin, Wyoming sampled by two horizontal wells (cut parallel or nearly parallel to bedding and at a high angle to steeply dipping Fractures) have 41.5 m of rock in four cores at depths of 4538–4547 m. Cores intersect older E-striking Set 1 Fractures are abutted by or locally cross-cut by N-striking Set 2 Fractures. Both sets contain quartz and Porosity. Sequenced using quartz crack-seal cement texture maps, Set 1 fluid inclusion assemblage (FIA) trapping temperatures increase progressively from 140 to 165°C then decrease to c . 150°C, compatible with Fracture opening over c . 15 Ma during rapid burial followed by uplift in Eocene–Oligocene time. Set 2 opened at c . 160°C, probably near maximum burial. After a period of quiescence, Set 2 reopened at c . 5 Ma at c . 140°C, on a cooling trajectory. Intermittent Set 2 movement could reflect local basement-involved fault movement, followed after a pause by further Set 2 reactivation in the modern stress field during uplift. Interpretations are sensitive to available burial/thermal histories, which have considerable uncertainty.
Géraud Yves - One of the best experts on this subject based on the ideXlab platform.
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Quantification of bound water content, interstitial Porosity and Fracture Porosity in the sediments entering the North Sumatra subduction zone from Cation Exchange Capacity and IODP Expedition 362 resistivity data
'Elsevier BV', 2020Co-Authors: Dutilleul Jade, Bourlange Sylvain, Conin Marianne, Géraud YvesAbstract:In this study, we investigate Porosity evolution through the sedimentary input section of the North Sumatra Subduction zone by quantifying interstitial Porosity, bound water content and Fracture Porosity based on IODP Expedition 362 data and post-cruise chemical analyses. During IODP Expedition 362, total Porosity of the sedimentary section entering the North Sumatra subduction zone was measured. This total Porosity is derived from the total water content of core samples thus including pore water and water bound to hydrous minerals like smectite. Clay mineral composition varies over the sedimentary section and is mainly kaolinite/illite in the Nicobar Fan units and smectite/illite in the prefan pelagic unit below. The prefan pelagic unit shows anomalously high total Porosity values and is stratigraphically correlated to a high amplitude negative polarity (HANP) seismic reflector located landward. This HANP reflector has been previously interpreted as a porous fluid-rich layer where the d{\'e}collement may develop along parts of the margin as a consequence of pore pressure buildup. We estimate clay bound water content from Cation Exchange Capacity (CEC) which gives information about the smectite/illite composition and soluble chloride content data. Interstitial Porosity corresponds to onboard total Porosity corrected from clay bound water and is more relevant in terms of sediment compaction state and fluid flow properties. Interstitial Porosity versus vertical effective stress curve shows no evidence of undercompaction and suggests that the input section 2 has been experiencing normal consolidation due to high sediment accumulation rate. The Porosity anomaly observed in the prefan pelagic unit results from the local occurrence of water-bearing minerals like smectite rather than excess pore pressure, which might, however, buildup more landward in the basin. We also estimate Fracture Porosity using a resistivity model for shales used in previous works based on wireline resistivity log and show that Fracture Porosity yields 4-6% in damaged parts of the sedimentary section investigated
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Quantification of bound water content, interstitial Porosity and Fracture Porosity in the sediments entering the North Sumatra subduction zone from Cation Exchange Capacity and IODP Expedition 362 resistivity data
'Elsevier BV', 2020Co-Authors: Dutilleul Jade, Bourlange Sylvain, Conin Marianne, Géraud YvesAbstract:International audienceIn this study, we investigate Porosity evolution through the sedimentary input section of the North Sumatra Subduction zone by quantifying interstitial Porosity, bound water content and Fracture Porosity based on IODP Expedition 362 data and post-cruise chemical analyses. During IODP Expedition 362, total Porosity of the sedimentary section entering the North Sumatra subduction zone was measured. This total Porosity is derived from the total water content of core samples thus including pore water and water bound to hydrous minerals like smectite. Clay mineral composition varies over the sedimentary section and is mainly kaolinite/illite in the Nicobar Fan units and smectite/illite in the prefan pelagic unit below. The prefan pelagic unit shows anomalously high total Porosity values and is stratigraphically correlated to a high amplitude negative polarity (HANP) seismic reflector located landward. This HANP reflector has been previously interpreted as a porous fluid-rich layer where the décollement may develop along parts of the margin as a consequence of pore pressure buildup. We estimate clay bound water content from Cation Exchange Capacity (CEC) which gives information about the smectite/illite composition and soluble chloride content data. Interstitial Porosity corresponds to onboard total Porosity corrected from clay bound water and is more relevant in terms of sediment compaction state and fluid flow properties. Interstitial Porosity versus vertical effective stress curve shows no evidence of undercompaction and suggests that the input section 2 has been experiencing normal consolidation due to high sediment accumulation rate. The Porosity anomaly observed in the prefan pelagic unit results from the local occurrence of water-bearing minerals like smectite rather than excess pore pressure, which might, however, buildup more landward in the basin. We also estimate Fracture Porosity using a resistivity model for shales used in previous works based on wireline resistivity log and show that Fracture Porosity yields 4-6% in damaged parts of the sedimentary section investigated
