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• W2082848989 abstract "PreviousNext No AccessUnconventional Resources Technology Conference, Denver, Colorado, 12-14 August 2013Relative Permeability in a Shale Formation in Colombia Using Digital Rock PhysicsAuthors: Maria T. CantisanoDora P. RestrepoSandra CespedesJonas ToelkeAvrami GraderMichael SuhrerJoel WallsMaria T. Cantisano1Ecopetrol, Bogota, ColombiaSearch for more papers by this author, Dora P. Restrepo1Ecopetrol, Bogota, ColombiaSearch for more papers by this author, Sandra Cespedes1Ecopetrol, Bogota, ColombiaSearch for more papers by this author, Jonas Toelke2Ingrain Inc., Houston, USASearch for more papers by this author, Avrami Grader2Ingrain Inc., Houston, USASearch for more papers by this author, Michael Suhrer2Ingrain Inc., Houston, USASearch for more papers by this author, and Joel Walls2Ingrain Inc., Houston, USASearch for more papers by this authorhttps://doi.org/10.1190/urtec2013-092 SectionsAboutPDF/ePub ToolsAdd to favoritesDownload CitationsTrack CitationsPermissions ShareFacebookTwitterLinked InRedditEmail Abstract URTeC 1562626 As more organic rich mudstone resource plays are developed internationally, the need to understand flow potential and long term well performance increases dramatically. Many international locations have limited infrastructure for the economic development of these low permeability formations. Therefore, operators require comprehensive rock data and careful reservoir modeling to help reduce the risk of early-stage development. This paper describes the methods and results of a project designed to quantify the range of expected permeability and relative permeability in samples from a shale formation in Colombia. Porosity versus absolute permeability trends were determined for about 44 well samples using digital rock physics (DRP) methods. Results show rock quality that is equal or better than many prolific North American shales, including Marcellus and Eagle Ford. These samples average about 6% organic material content by volume. The total porosity range observed is from about 3 to 15%. For total porosity of 4% or above, the horizontal permeability is generally above 100 nanodarcy (nd). For porosity of 8%, horizontal permeability is typically 1000nd or more. From these 44 samples, several were selected for relative permeability analysis. Using a Lattice-Boltzmann numerical method, imbibition relative permeability computations (increasing fractional flow of water) were performed for oil-water systems for different scenarios including different contact angles ranging from oil to water wet, and different API values leading to different viscosity ratios. Keywords: permeability, rock geophysics, porosity, water, unconventionalPermalink: https://doi.org/10.1190/urtec2013-092FiguresReferencesRelatedDetailsCited ByRelative permeability of tight hydrocarbon systems: An experimental studyFuel, Vol. 294Impact of Fluid Heterogeneity on Tight Unconventional Well GOR PerformanceFahd Mohamad Alqahtani, Mohamad Majzoub Dahouk, Curtis H. Whitson, and Ellie Chuparova30 December 2020Experimental Evaluation of Relative Permeability in Tight Oil Systems: Examples from North American Tight Oil PlaysA. Ghanizadeh, C. Song, C.R. Clarkson, and A. Younis30 December 2020GOR Performance for Tight Unconventional Wells with Layer-Wise Fluid Heterogeneity1 December 2020Hydrocarbon Findings in Challenging Shilaif in Western UAE Core Analysis Approach9 November 2020Impact of Heterogeneity on Producing GOR for Tight Unconventional Wells24 September 2020Gas Transport in Shale Nanopores with Miscible ZoneGeofluids, Vol. 2020Modelling shale spontaneous water intake using semi‐analytical and numerical approaches7 December 2018 | The Canadian Journal of Chemical Engineering, Vol. 97, No. S1A Fractal Model for Gas–Water Relative Permeability in Inorganic Shale with Nanoscale Pores23 January 2018 | Transport in Porous Media, Vol. 122, No. 2An analytical model for relative permeability in water-wet nanoporous mediaChemical Engineering Science, Vol. 174Relative permeability estimates for Wolfcamp and Eagle Ford shale samples from oil, gas and condensate windows using adsorption-desorption measurementsFuel, Vol. 208Estimating Mudrock Oil-Water Relative Permeability Curves Using Digital Rock PhysicsChristopher J. Landry, Maša Prodanović, Rob Reed, Peter Eichhubl, and Kishore Mohanty12 September 2017Hydraulic properties of porous sintered glass bead systems18 March 2017 | Granular Matter, Vol. 19, No. 2A Theory for Relative Permeability of Unconventional Rocks With Dual-Wettability Pore Network15 July 2016 | SPE Journal, Vol. 21, No. 06Factors Controlling Fluid Migration and Distribution in the Eagle Ford Shale15 June 2016 | SPE Reservoir Evaluation & Engineering, Vol. 19, No. 03Relative Permeability of Unconventional Rocks with Dual-Wettability Pore-NetworkQing Lan, Mahmood Reza Yassin, Ali Habibi, Hassan Dehghanpour, and James Wood12 August 2015Relative Permeability of Unconventional Rocks with Dual-Wettability Pore-Network4 August 2015Factors Controlling Fluid Migration and Distribution in the Eagle Ford Shale30 September 2014 Unconventional Resources Technology Conference, Denver, Colorado, 12-14 August 2013ISSN (online):2159-6832Copyright: 2013 Pages: 1229 publication data© 2013 Published in electronic format with permission by the Society of Exploration Geophysicists, American Association of Petroleum Geologists, and Society of Petroleum EngineersPublisher:Unconventional Resources Technology ConferenceSociety of Exploration Geophysicists HistoryPublished: 26 Sep 2013 CITATION INFORMATION Maria T. Cantisano, Dora P. Restrepo, Sandra Cespedes, Jonas Toelke, Avrami Grader, Michael Suhrer, and Joel Walls, (2013), Relative Permeability in a Shale Formation in Colombia Using Digital Rock Physics, SEG Global Meeting Abstracts : 909-915. https://doi.org/10.1190/urtec2013-092 Plain-Language Summary Keywordspermeabilityrock geophysicsporositywaterunconventionalPDF DownloadLoading ..." @default.
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• W2082848989 title "Relative Permeability in a Shale Formation in Colombia Using Digital Rock Physics" @default.
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