The Experts below are selected from a list of 64251 Experts worldwide ranked by ideXlab platform
Federico F Krause - One of the best experts on this subject based on the ideXlab platform.
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characterization of fine scale Rock Structure and differences in mechanical properties in tight oil reservoirs an evaluation at the scale of elementary lithological components combining photographic and x ray computed tomographic imaging profile permeability and microhardness testing
2016Co-Authors: Nisael A Solano, Christopher R Clarkson, Federico F KrauseAbstract:Abstract Optimal development of tight-oil resources requires better petrophysical understanding of several key reservoir and mechanical properties. We highlight these for the Cardium Formation at the Pembina field, where controls on these properties appear to occur within elementary lithological components (ELCs) at the cm- to sub-cm scale moderated in part by the effects of synsedimentary bioturbation. This complexity in reservoir behavior necessitates new and innovative approaches for petrophysical property estimation, which is the subject of the current work. The workflow outlined starts with the quantification of the volumetric distribution of ELCs. For this purpose, 360° photographic imaging was used to first identify ELCs, and then quantify their volumetric percentages in whole core. This initial step is limited to the exposed surfaces of the core, consequently we used X-ray computed tomography (XRCT) in order to project the ELCs volumetric distribution into the core interior. The correlation between CT number, mineralogy, and bulk density of the Rock further allowed porosity to be calculated from XRCT and shed light on its distribution throughout the core interior. Variations in fine-scale permeability were evaluated by collecting pressure-decay profile permeability measurements across a core slab surface following a 5 × 5 mm-2D grid. Relationships between ELCs permeability and porosity were then generated and, when combined with the volumetric distribution of ELCs previously assessed, enabled a 3D distribution of reservoir quality at the mm-scale throughout the core. Finally, microhardness data was collected on the same 2D grid enabling ELC-scale quantification of mechanical properties. Reservoir properties of whole core samples identified in previous publications appear to be reasonably predicted when utilizing ELCs-specific permeability versus porosity transforms and volumetric percentages generated in this study, thus demonstrating scale-up potential.
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characterization of fine scale Rock Structure and differences in mechanical properties in tight oil reservoirs an evaluation at the scale of elementary lithological components combining photographic and x ray computed tomographic imaging profile permeability and microhardness testing
2016Co-Authors: Nisael A Solano, Christopher R Clarkson, Federico F KrauseAbstract:Abstract Optimal development of tight-oil resources requires better petrophysical understanding of several key reservoir and mechanical properties. We highlight these for the Cardium Formation at the Pembina field, where controls on these properties appear to occur within elementary lithological components (ELCs) at the cm- to sub-cm scale moderated in part by the effects of synsedimentary bioturbation. This complexity in reservoir behavior necessitates new and innovative approaches for petrophysical property estimation, which is the subject of the current work. The workflow outlined starts with the quantification of the volumetric distribution of ELCs. For this purpose, 360° photographic imaging was used to first identify ELCs, and then quantify their volumetric percentages in whole core. This initial step is limited to the exposed surfaces of the core, consequently we used X-ray computed tomography (XRCT) in order to project the ELCs volumetric distribution into the core interior. The correlation between CT number, mineralogy, and bulk density of the Rock further allowed porosity to be calculated from XRCT and shed light on its distribution throughout the core interior. Variations in fine-scale permeability were evaluated by collecting pressure-decay profile permeability measurements across a core slab surface following a 5 × 5 mm-2D grid. Relationships between ELCs permeability and porosity were then generated and, when combined with the volumetric distribution of ELCs previously assessed, enabled a 3D distribution of reservoir quality at the mm-scale throughout the core. Finally, microhardness data was collected on the same 2D grid enabling ELC-scale quantification of mechanical properties. Reservoir properties of whole core samples identified in previous publications appear to be reasonably predicted when utilizing ELCs-specific permeability versus porosity transforms and volumetric percentages generated in this study, thus demonstrating scale-up potential.
Nisael A Solano - One of the best experts on this subject based on the ideXlab platform.
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characterization of fine scale Rock Structure and differences in mechanical properties in tight oil reservoirs an evaluation at the scale of elementary lithological components combining photographic and x ray computed tomographic imaging profile permeability and microhardness testing
2016Co-Authors: Nisael A Solano, Christopher R Clarkson, Federico F KrauseAbstract:Abstract Optimal development of tight-oil resources requires better petrophysical understanding of several key reservoir and mechanical properties. We highlight these for the Cardium Formation at the Pembina field, where controls on these properties appear to occur within elementary lithological components (ELCs) at the cm- to sub-cm scale moderated in part by the effects of synsedimentary bioturbation. This complexity in reservoir behavior necessitates new and innovative approaches for petrophysical property estimation, which is the subject of the current work. The workflow outlined starts with the quantification of the volumetric distribution of ELCs. For this purpose, 360° photographic imaging was used to first identify ELCs, and then quantify their volumetric percentages in whole core. This initial step is limited to the exposed surfaces of the core, consequently we used X-ray computed tomography (XRCT) in order to project the ELCs volumetric distribution into the core interior. The correlation between CT number, mineralogy, and bulk density of the Rock further allowed porosity to be calculated from XRCT and shed light on its distribution throughout the core interior. Variations in fine-scale permeability were evaluated by collecting pressure-decay profile permeability measurements across a core slab surface following a 5 × 5 mm-2D grid. Relationships between ELCs permeability and porosity were then generated and, when combined with the volumetric distribution of ELCs previously assessed, enabled a 3D distribution of reservoir quality at the mm-scale throughout the core. Finally, microhardness data was collected on the same 2D grid enabling ELC-scale quantification of mechanical properties. Reservoir properties of whole core samples identified in previous publications appear to be reasonably predicted when utilizing ELCs-specific permeability versus porosity transforms and volumetric percentages generated in this study, thus demonstrating scale-up potential.
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characterization of fine scale Rock Structure and differences in mechanical properties in tight oil reservoirs an evaluation at the scale of elementary lithological components combining photographic and x ray computed tomographic imaging profile permeability and microhardness testing
2016Co-Authors: Nisael A Solano, Christopher R Clarkson, Federico F KrauseAbstract:Abstract Optimal development of tight-oil resources requires better petrophysical understanding of several key reservoir and mechanical properties. We highlight these for the Cardium Formation at the Pembina field, where controls on these properties appear to occur within elementary lithological components (ELCs) at the cm- to sub-cm scale moderated in part by the effects of synsedimentary bioturbation. This complexity in reservoir behavior necessitates new and innovative approaches for petrophysical property estimation, which is the subject of the current work. The workflow outlined starts with the quantification of the volumetric distribution of ELCs. For this purpose, 360° photographic imaging was used to first identify ELCs, and then quantify their volumetric percentages in whole core. This initial step is limited to the exposed surfaces of the core, consequently we used X-ray computed tomography (XRCT) in order to project the ELCs volumetric distribution into the core interior. The correlation between CT number, mineralogy, and bulk density of the Rock further allowed porosity to be calculated from XRCT and shed light on its distribution throughout the core interior. Variations in fine-scale permeability were evaluated by collecting pressure-decay profile permeability measurements across a core slab surface following a 5 × 5 mm-2D grid. Relationships between ELCs permeability and porosity were then generated and, when combined with the volumetric distribution of ELCs previously assessed, enabled a 3D distribution of reservoir quality at the mm-scale throughout the core. Finally, microhardness data was collected on the same 2D grid enabling ELC-scale quantification of mechanical properties. Reservoir properties of whole core samples identified in previous publications appear to be reasonably predicted when utilizing ELCs-specific permeability versus porosity transforms and volumetric percentages generated in this study, thus demonstrating scale-up potential.
Christopher R Clarkson - One of the best experts on this subject based on the ideXlab platform.
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characterization of fine scale Rock Structure and differences in mechanical properties in tight oil reservoirs an evaluation at the scale of elementary lithological components combining photographic and x ray computed tomographic imaging profile permeability and microhardness testing
2016Co-Authors: Nisael A Solano, Christopher R Clarkson, Federico F KrauseAbstract:Abstract Optimal development of tight-oil resources requires better petrophysical understanding of several key reservoir and mechanical properties. We highlight these for the Cardium Formation at the Pembina field, where controls on these properties appear to occur within elementary lithological components (ELCs) at the cm- to sub-cm scale moderated in part by the effects of synsedimentary bioturbation. This complexity in reservoir behavior necessitates new and innovative approaches for petrophysical property estimation, which is the subject of the current work. The workflow outlined starts with the quantification of the volumetric distribution of ELCs. For this purpose, 360° photographic imaging was used to first identify ELCs, and then quantify their volumetric percentages in whole core. This initial step is limited to the exposed surfaces of the core, consequently we used X-ray computed tomography (XRCT) in order to project the ELCs volumetric distribution into the core interior. The correlation between CT number, mineralogy, and bulk density of the Rock further allowed porosity to be calculated from XRCT and shed light on its distribution throughout the core interior. Variations in fine-scale permeability were evaluated by collecting pressure-decay profile permeability measurements across a core slab surface following a 5 × 5 mm-2D grid. Relationships between ELCs permeability and porosity were then generated and, when combined with the volumetric distribution of ELCs previously assessed, enabled a 3D distribution of reservoir quality at the mm-scale throughout the core. Finally, microhardness data was collected on the same 2D grid enabling ELC-scale quantification of mechanical properties. Reservoir properties of whole core samples identified in previous publications appear to be reasonably predicted when utilizing ELCs-specific permeability versus porosity transforms and volumetric percentages generated in this study, thus demonstrating scale-up potential.
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characterization of fine scale Rock Structure and differences in mechanical properties in tight oil reservoirs an evaluation at the scale of elementary lithological components combining photographic and x ray computed tomographic imaging profile permeability and microhardness testing
2016Co-Authors: Nisael A Solano, Christopher R Clarkson, Federico F KrauseAbstract:Abstract Optimal development of tight-oil resources requires better petrophysical understanding of several key reservoir and mechanical properties. We highlight these for the Cardium Formation at the Pembina field, where controls on these properties appear to occur within elementary lithological components (ELCs) at the cm- to sub-cm scale moderated in part by the effects of synsedimentary bioturbation. This complexity in reservoir behavior necessitates new and innovative approaches for petrophysical property estimation, which is the subject of the current work. The workflow outlined starts with the quantification of the volumetric distribution of ELCs. For this purpose, 360° photographic imaging was used to first identify ELCs, and then quantify their volumetric percentages in whole core. This initial step is limited to the exposed surfaces of the core, consequently we used X-ray computed tomography (XRCT) in order to project the ELCs volumetric distribution into the core interior. The correlation between CT number, mineralogy, and bulk density of the Rock further allowed porosity to be calculated from XRCT and shed light on its distribution throughout the core interior. Variations in fine-scale permeability were evaluated by collecting pressure-decay profile permeability measurements across a core slab surface following a 5 × 5 mm-2D grid. Relationships between ELCs permeability and porosity were then generated and, when combined with the volumetric distribution of ELCs previously assessed, enabled a 3D distribution of reservoir quality at the mm-scale throughout the core. Finally, microhardness data was collected on the same 2D grid enabling ELC-scale quantification of mechanical properties. Reservoir properties of whole core samples identified in previous publications appear to be reasonably predicted when utilizing ELCs-specific permeability versus porosity transforms and volumetric percentages generated in this study, thus demonstrating scale-up potential.
Naohiko Tokashiki - One of the best experts on this subject based on the ideXlab platform.
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a new Rock mass quality rating system Rock mass quality rating rmqr and its application to the estimation of geomechanical characteristics of Rock masses
2014Co-Authors: Ömer Aydan, Resat Ulusay, Naohiko TokashikiAbstract:The qualitative description of Rock masses by means of classification systems and subsequent correlation to establish engineering quantities or design parameters has become one of the most challenging topics in Rock engineering. Many Rock mass classification systems have been proposed for Rock masses with the consideration of a particular Rock Structure and/or specific purposes. Therefore, direct utilization of these systems, in their original form, for the characterization of complex Rock mass conditions is not always possible. This is probably one of the reasons why Rock engineers continue to develop new systems or modify and extend current ones. The recent tendency is to obtain Rock mass properties from the utilization of properties of intact Rock and Rock classification indexes, which have some drawbacks. In this study, it is aimed to propose a new Rock mass quality rating system designated as Rock Mass Quality Rating (RMQR). This new Rock mass rating system is used to estimate the geomechanical properties of Rock masses. In the first part of this paper, the input parameters of RMQR and their ratings are given and discussed. In the second part, the unified formula proposed by the first author is adopted for the new Rock mass rating system for estimating the Rock mass properties and compared with the results of the in situ tests carried out in Japan and those estimated from some empirical relationships developed by other investigators, and the outcomes of these studies are presented and discussed.
S. Demirdag - One of the best experts on this subject based on the ideXlab platform.
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Assessment of the physical and mechanical variations of some travertines depend on the bedding plane orientation under physical weathering conditions
2015Co-Authors: N. Sengun, S. Demirdag, I. Ugur, Deniz Akbay, R. AltindagAbstract:Travertine has long been a popular material for stone tile flooring in many stages of construction projects due to having unique surface properties characterized by honeycomb Structure. Significant differences may be observed in terms of both visual appearances on the Rock surface and physical and mechanical behavior in the using area depending on the cutting direction. In this study, different cutting directions were applied to travertine blocks and the effects of freezing–thawing and thermal shock cycles on the Rock Structure were experimentally investigated. The changes in the physical and mechanical properties of three different travertine types, such as uniaxial compressive strength, flexural strength, Bohme abrasion resistance, capillary water absorption and P-wave velocity values depending on the bedding direction were evaluated under the effect of freezing–thawing and thermal shock tests for 10, 20, 30, and 40 cycles. Qualitative results show that the freezing–thawing cycles have a more destructive effect on the mechanical properties in comparison to thermal-shock cycles through perpendicular loading conditions to the bedding planes in travertines.
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thermal effect on the physical properties of carbonate Rocks
2010Co-Authors: H Yavuz, S. Demirdag, S CaranAbstract:Abstract The effect of thermal damage on the physical properties of five carbonate Rocks has been investigated. The tests were conducted on two marbles and three limestones, mainly composed of calcite but with different grain sizes, porosities, structural and textural characteristics. Cubic samples prepared from these Rocks were gradually heated to a specific temperature level of 100, 200, 300, 400 and 500 °C, and gradually cooled down to room temperature without causing thermal shock in order to investigate the effect of heating temperature on physical properties such as microStructure, bulk density, effective porosity and P-wave velocity. Microscopic investigations from thin sections showed that damage in Rocks at elevated temperatures was induced in different severity depending on grain size, porosity, structural and textural characteristics. Colour changes were also observed in porous limestones (Lymra and Travertine) due to organic material. In accordance with the degree of calcite dilation depending on heating temperature and in turn new microcrack occurrence, separation along intragrain and/or intergrain boundaries and widening of existing cracks, P-wave velocity decreased to various levels of the initial value, whereas porosity increased. Microscopic analyses and P-wave velocity measurements indicate that compaction of Rock Structure up to 150 °C occurred and induced calcite dilation had no significant damage effect on the Rock material. Compaction of Rock Structure led to an increase in P-wave velocity and slight decrease in porosity. Most of the damage occurred within 24 h of heating time and further heating treatments brought relatively minor changes in physical properties. Damage intensity was well explained with P-wave velocity and effective porosity values depending on temperature increase.
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the effect of using different polymer and cement based materials in pore filling applications on technical parameters of travertine stone
2009Co-Authors: S. DemirdagAbstract:Abstract The usage of marbles as a natural building and facing stone shows a gradually rising trend in civil sector all over the world. Due to natural motion, Structure of marbles consists of many cracks and holes during formation of Rocks. Cracks and holes in the marbles generally increase the wastage ratio and operating costs during production of marbles. Normally, the color consistency, brightness of the colors, hardness, strength, non-porous smooth surface as a hygienic Structure are desired properties in the usage of flooring and facing stones. In this study, application of some pore filling methods in travertine and their effects on technical parameters of the Rock Structure were experimentally investigated. Although travertine has high porosity and is composed of different sizes of pores in its Structure, it has a wide usage area in the construction and facing stone industry. Its processing is very easy and is much cheaper than the other marble types. Two different applications were mainly used for the pore filling process. These methods are polyester filling technique and cement filling technique. The use of cement filling method is widely applied in travertine production. The effects of these methods on the Rock Structure were analyzed and the most suitable filling technique was determined based on the technical data of Rock parameters. In this study, in addition to the effective use of cement as a filler material in a travertine stone, different ratios of polymer admixtures as a Stuff (ST) and Poliacrilamid (PA) were used to evaluate the collapse of the filling material through the pores with optimum setting time. These materials were used as a replacement of the cement and calcite with the ratios of 0.1%, 0.5%, 1.0%, 1.5% and 2.0%. Test samples were prepared in the form of 40 cm × 40 cm × 1.2 cm tiles and different ratios of the mixture of cement, calcite and polymer materials were applied on the Rock surface. These samples were analyzed in terms of water absorption, point load index and unit volume weight measurements by using appropriate standards, TS 699 and ISRM. According to test results, it was tried to compare the filled and unfilled material properties and to obtain optimum ST–PA and cement usage ratio with respect to improving polishing quality, physical and technical parameters of Rock.
