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Fourth Naturally Fractured Reservoir Workshop
- Conference date: February 11-13, 2020
- Location: Ras Al Khaimah, United Arab Emirates
- Published: 11 February 2020
21 - 27 of 27 results
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Oman’s thinnest oil column produced so far in a naturally fractured reservoir under GOGD
Authors C. Volery, L. Bazalgette, S. Shuaili, F. Aljiroudi, I. Kobenko, P. Almeida, A. Zahibi, S. Omairi, H. Sukaity and M. GharbiSummaryAn ambitious project recently undertaken by PDO is aiming at producing the thinnest oil column so far in a naturally fractured carbonate reservoir by cold gas oil gravity drainage.
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Integrated analysis of fracture corridors
Authors S. Viseur, J. Lamarche and B. GauthierSummaryFracture corridors are singular Mode I fracture clusters where the density of highly persistent fractures is anomalously high with a complex and unpredictable fracture architecture in 3D. In reservoirs, fracture corridors have major impacts on fluid flow. Hence, the 3D detection and modelling of the fracture networks within corridors is of paramount importance in order to restore their 3D nature from restricted 1D data sets in underground reservoirs. In this poster, we present an integrated approach of corridors combining a geometrical characterization of corridors from structural and numerical field survey and a numerical method to detect and locate the corridors from 1D data (scan lines or underground wells).
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A novel way to decipher field performance in a NFR carbonate field
By P. OlivierSummaryA novel way to decipher field performance in a NFR carbonate field.
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Comparison of Fracture Intensity Measured in Outcrop and μCT Core Plugs in a Carbonate Reservoir Analogue
Authors S. Kokkalas, R. Jones, M. Wilkinson, S. Daniels, S. Gilment and S. NizamuddinSummaryThe porosity and permeability structure of fractured reservoirs is highly heterogeneous, however typical sub-surface data are unable to quantify this heterogeneity across scales of analysis that are most relevant for fluid flow. Comprehensive analysis of outcrop analogues can provide detailed, quantitative characterisation of the fracture network to produce robust ranges of values for input to discrete fracture network (DFN) or other fracture models. We compare fracture intensities measured from 3D X-Ray Computed Micro-Tomography with those calculated from scan lines measured along 1D tape measure transects in outcrop, and from multiple virtual scan lines in 3D point cloud data acquired from terrestrial laser scanning (lidar) and digital photogrammetry. Micro-tomography is also useful to help extend understanding of fracture intensities to analysis of fracture porosity.
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Interplay of heat transport and fracture aperture in fractured reservoirs
Authors L.F.L. Torres, S. Salimzadeh and H.M. NickSummaryIn this study, the interaction among thermal-hydraulic-mechanical (THM) processes in fractured reservoirs is investigated by means of numerical experiments. Particularly, the impact of fracture geometry, the injection rate and rock matrix permeability on heat transport in such reservoirs is studied. To do this, a fully coupled thermal-hydraulic-mechanical finite element is utilised to consider non-isothermal flow through the rock matrix and fractures subjected to mechanical deformation. The resulting temperature field is observed for different scenarios considering a doublet system in which cold fluid is injected into an injection well, and hot fluid is extracted from the production well. The simulations strongly support that in fractured systems depending on fracture density and matrix permeability, the arrival time of the cold front and the extent of the cold plume vary.
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Bridging multi-scale data set for fracture characterization and their stress sensitivity evaluation in the near-wellbore region: Results from a novel workflow
Authors S. Randazzo, C. Barton, Y. Bouzida, G. Izadi, J. Tinnin, J. Franquet, S. Perumalla, E. Cazeneuve, A. Ghadimipour and G. ZhunussovaSummaryIntegrated fractures characterization is a critical for the development of unconventional carbonate reservoirs. Having relevant conceptual geological and geomechanical models tied to well data helps to optimize the positive impact of natural fractures on production so that appropriate well placement and completion/hydraulic fracture will maximize the intersection of well with target sweet spots while avoiding faults that may connect with water or H2S geohazards.
While Borehole Images (BHI), due to their high resolution, are cornerstone for providing precise data and orientation of fractures intersected by the well. Unfortunately, they have a shallow wellbore depth of investigation. While, the Patented deep shear methodology allows identification of features up to 110 feet away from the borehole and confirms fracture hierarchies and fracture bed interaction.
A data integration and 3D visualization of the BHI, DSWI, geomechanical and seismic data were analyzed in the same field. The results were very promising to bridge between the different scales of features observed. It has been instructive to validate the systematic integration within same wells. This has provided additional insight for the sub-surface team to propose hierarchical reservoir characterization models and for the engineering team to understand better the geological structures prior and post to fracking.
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Importance of diagenesis in naturaly fractured reservoirs
By E. UkarSummaryDiagenesis affects fracture properties. Fracture cements contain information about temperature, pressure, and fluid composition during and after deformation, as well as fracture timing. Cathodoluminescence (CL) imaging of fracture cements is key to unravelling the evolution of fractures, but limitations of this technique have heretofore limited our ability to image ubiquitous carbonate cements. Here I show three examples of carbonate-cemented, naturally fractured reservoirs for which recent advances in SEM-CL imaging enabled determination of fracture formation timing and/or sealing. Extensional fault zones in the Apennines contain carbonate cements precipitated in the vadose/phreatic zone during and after faulting. Fault cores show higher porosity and permeability than the host rock, but cement linings and reactivation associated with coseismic slip caused permeability reduction. In the Vaca Muerta Formation, a combination of thrust fault-bounded kinematic indicators within bed parallel veins (BPVs) and fluid inclusion microthermometry indicate BPVs formed in the Late Cretaceous, whereas bed-perpendicular fractures formed in the Paleocene. Finally, cross-cutting relationships, isotopic analyses, and radiometric dating of fracture and vug-filling cements indicate the main reservoir porosity-forming event in Ordovician carbonates of the Halahatang oilfield, Tarim Basin, occurred in the Silurian-Devonian at depths of as much as ∼1.5–2 km. Dissolution was related to fractures and faults.
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