The content of this course encompasses the examination, modeling, and simulation of Naturally Fractured Reservoirs (NFRs). It delves into the characterization of NFRs, including the establishment of constitutive relationships for multiphase flow in both the matrix and fractures. Furthermore, the course explores topics such as the transfer of fluids between fractures and matrix, and the variation of flow properties at different scales.

Additionally, the course explores the concept of flow-based upscaling, specifically focusing on permeability and relative permeability, taking into account emerging flow structures and instabilities, such as fracture-assisted viscous fingering.

Course Objectives:

Analysis supported by findings from cm- to HM-scale physical experiments and numerical simulations
Observations and dynamic data are used to address NFR behavior on the field-scale
The information shared in this course underpins a novel NFR characterization and reservoir simulation workflow that begins with statistical fracture characterization in the subsurface, including geomechanical techniques for the prediction of fracture geometrical arrangement, connectivity and aperture and takes into account the in situ stress state. It will be shown how the latter can be inferred from the lithostatic load, borehole breakouts and drilling-induced tensile fractures. The discussed workflow progresses with the computation of grid-block scale fracture - matrix ensemble properties and concludes with the field-scale simulation of NFRs
The course also tries to establish what dynamic data reveal about the role of fractures or faults in any particular NFR and how these diagnostics should be used to guide data collection, history matching and predictive simulations
Many of the conclusions drawn in this course rest on results from Discrete Fracture and (rock)-Matrix (DFM) simulations carried out on unstructured hybrid FEM-FVM scale models. Therefore, the foundations of the DFM and simplifications made / associated assumptions are explained as well
The DFM approach is compared and contrasted with existing fracture modelling and flow simulation techniques, including an analysis and discussion of the pros and cons of field-scale dual porosity modelling

Who Should Attend?

A reservoir engineer or geoscientist working on fractured reservoirs
A basic understanding of reservoir characterization and modeling, multiphase fluid flow in porous media and numerical methods is recommended.

Course Outlines:

Mechanics, statistics and permeability of naturally fractured reservoirs
Naturally fractured reservoirs and THMC processes
Fracture mechanics relevant to porous rocks
Fracture pattern formation and aperture distributions under in situ conditions
Fracture statistics and their measurement
Fracture permeability and anisotropy of fractured rock
Parameterization of fracture-matrix dual continua models with (static) field data
Fractures versus faults
Fracture development and modification due to chemical reactions
Fluid flow in naturally fractured reservoirs
The unstructured spatially adaptive discretization of DFM simulation models: hybrid FEM-FVM formulation for DFM simulation
Constitutive relationships for multiphase fracture flow and fracture matrix transfer
Single-phase flow in fractured rock
Single-phase transport through fractured rock
Multiphase flow in fractures and rock matrix
Flow-based upscaling of fracture-matrix ensemble relative permeability

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