Limitations in Numerical Well Rest Modelling of Fractured Carbonate Rocks P. W. Corbett; P. W. Corbett Heriot-Watt University Search for other works by this author on: This Site Google Scholar S.. Geiger; S.. Geiger Heriot-Watt University Search for other works by this author on: This Site Google Scholar L.. Borges; L.. Borges Petrobras Search for other works by this author on: This Site Google Scholar M.. Garayev; M.. Garayev Heriot-Watt University Search for other works by this author on: This Site Google Scholar J. G. Gonzalez; J. G. Gonzalez Ecopetrol Search for other works by this author on: This Site Google Scholar C.. Valdez C.. Valdez Dubai Petroleum Search for other works by this author on: This Site Google Scholar Paper presented at the SPE EUROPEC/EAGE Annual Conference and Exhibition, Barcelona, Spain, June 2010. Paper Number: SPE-130252-MS https://doi.org/10.2118/130252-MS Published: June 14 2010 Cite View This Citation Add to Citation Manager Share Icon Share Twitter LinkedIn Get Permissions Search Site Citation Corbett, P. W., Geiger, S.. , Borges, L.. , Garayev, M.. , Gonzalez, J. G., and C.. Valdez. "Limitations in Numerical Well Rest Modelling of Fractured Carbonate Rocks." Paper presented at the SPE EUROPEC/EAGE Annual Conference and Exhibition, Barcelona, Spain, June 2010. doi: https://doi.org/10.2118/130252-MS Download citation file: Ris (Zotero) Reference Manager EasyBib Bookends Mendeley Papers EndNote RefWorks BibTex Search Dropdown Menu toolbar search search input Search input auto suggest filter your search All ContentAll ProceedingsSociety of Petroleum Engineers (SPE)SPE Europec featured at EAGE Conference and Exhibition Search Advanced Search Abstract Interpreting well-tests in (fractured) carbonate reservoirs poses significant challenges because these reservoirs often demonstrate triple porosity system (fracture-matrix-vugs) characteristics. However, there is no "unique" triple porosity system: The matrix can behave as a double porosity/dual permeability system whilst the fractures provide the third system; there may be two fracture systems and a single matrix; there may be vugs (macropores), mesopores and micropores to provide very large contrasts in matrix permeabilities. Modelling these systems is challenging because of the need to include heterogeneity for the matrix (or multiple matrices) and fracture(s) and determine the correct coupling between these systems.The typical well test response in fractured systems – the classic double porosity "V" – can provide factors such as ω and λ as a description of fracture-matrix interaction (storativity ratio and the interporosity flow coefficient, respectively). Understanding how these two parameters relate to the description of matrix and fracture properties in triple porosity systems requires exploration of new scenarios in numerical well test modelling (sometimes called "geological well testing"). In this paper, we set out some of the reservoir description, modelling and simulation challenges to provide guidance on how to set up systematic models and determine the appropriate family of geotype (families of closely related pressure derivative response) curves for fractured carbonate systems in order to understand the interpretation of ω and λ. Keywords: permeability contrast, pressure transient, drillstem/well testing, fractured braided fluvial system, braided fluvial system, reservoir simulation, complex reservoir, carbonate reservoir, porosity, fracture aperture Subjects: Hydraulic Fracturing, Reservoir Characterization, Reservoir Simulation, Formation Evaluation & Management, Unconventional and Complex Reservoirs, Drillstem/well testing, Naturally-fractured reservoirs, Carbonate reservoirs Copyright 2010, Society of Petroleum Engineers You can access this article if you purchase or spend a download.