Modeling naturally fractured reservoirs (NFR) is regaining interest in the industry and academia thanks to the revolution in unconventional hydrocarbon and EOR in carbonate fractured reservoirs. This course provides an overview of naturally fractured reservoirs (NFR) and focuses on traditional and advanced methods to model NFR. The course includes: 1) Introduction on NFR: definitions, importance, detection methods, characterization; 2) Single porosity model: multiphase flow, matrix fracture interaction (diffusion, imbibition, infiltration), gridding, limitations; 3) dual porosity/dual-permeability models: derivations, shape factor, transfer functions, limitations; 4) Discrete fractured models; 2D/3D gridding simplifications; S)Advanced methods; Finite Element (FE), Control-Volume FE, Mixed FE; 6) DFN upscaling: static/dynamic upscaling, singlephase/multi-phase upscaling. Note: students are expected to have at least basic familiarity with: Multi phase flow in porous media, and programming in Matlab or Python.

 

This course addresses key fundamentals of reservoir engineering and reservoir simulation. Realistic hydrocarbon field cases will be considered. Students will get exposed to industry adopted workflows in reservoir modeling and management and will get familiarized with a commercial reservoir simulator. The course includes the following topics: 1) Basic concepts: hydrocarbon PVT/thermodynamics, material balance, uncertainty analysis, drive mechanisms, vertical equilibrium, capillarity and J-functions; 2)Primary depletion: recovery mechanism, performance evaluation; 3)Secondary depletion: displacement efficiency, BuckleyLeverett theory, mobility ratio, sweep efficiency, well placement, water flood evaluation, tracer concept; 4) Reservoir simulation: governing equations, linear/nonlinear solvers, IMPES/FI/AIM formulations, well model/control, numerical error, history-match concept, prediction uncertainties; S)Enhanced oil recovery (EOR): hydrocarbon trapping mechanisms, concepts of miscible/immiscible gas flood, chemical EOR, thermal EOR, EOR screening; 6)Field management: workflow, economics, decision analysis.

Oil and gas production rates from a well often undergo a declining behavior over time. Well productivity is a complex process that is a function of the hydrocarbon reservoir subsurface properties related to the fluids in places and the hosting environment. It is also related to the wellbore flow conditions from the reservoir to the surface. Well testing is an important technology that is frequently used in the industry. This technology consists of flow diagnostics (rates and pressure) to evaluate a well productivity or injectivity performance such as skin factor, non-Darcy effect, and storativity. It is also used to acquire insights about the reservoir properties such as connectivity, heterogeneity including fractures, flow regime, and drainage area. This course covers the fundamentals of well testing and discusses real field applications. The course includes : 1) fundamentals of flow in porous media; 2) introduction to decline-curve analysis; 3) Buildup-test analysis of slightly compressible fluids; 4) Analysis of oil and gas well flow and buildups tests; 5)Well-test in hydraulically fractured wells; 6) Well-test in naturally fractured reservoirs; 7) Interference and pulse testing; 8) well testing in unconventional reservoirs Note: students are expected to have at least basic familiarity with: Multi- phase flow in porous media, reservoir engineering, and programming in Matlab or Python