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E-334C - Reservoir Simulation Workshop Certification

10 days GRE/RESSIMU
Level
Advanced
Audience
  • Reservoir engineers, experienced reservoir geologists and production engineers willing to deepen their knowledge and get a practical insight in black-oil dynamic reservoir simulation
Purpose
  • To provide a thorough and practical understanding of dynamic reservoir simulation; covering principles of simulation as well as data reviewing and formatting, with an immediate application to a full field development project using real field case data
Learning Objectives
  • To deal with actual simulation dataset and perform basic history matching and production forecast study using dynamic reservoir simulation
  • To discuss the fundamental concepts of dynamic reservoir simulation
  • To build a simple reservoir simulation model (data gathering, data QC)
  • To carry out basic reservoir simulation study (data input, history matching and production forecast) from a real field case black-oil simulation model
  • To discuss, explain and justify choices in setting up a simple field development scheme including taking into account economics constraints
Ways and means
  • Intensive 10-days work alternating courses on black-oil Dynamic Reservoir Simulation using simple and didactic dataset and teamwork on a full field development project with deliverables to be presented to a joint IFP Training / Company jury in a plenary session
  • Coaching by industry experts throughout the period
  • Deliverables: a well-organized data set with input data and relevant results, a presentation and (optionally) a report

Part 1: Reservoir simulation course 5 days
  • Introduction to reservoir simulation
  • Physical aspects & basic laws
  • Mathematical & numerical aspects (diffusivity, transport & general equations)
  • Types of reservoir simulation models: black oil, compositional, thermal, chemical and double porosity model
  • Introduction to the simulator (ECLIPSE)
  • Simulation software presentation
  • Practical exercise (Building a model from A to Z)
  • Space & time discretization
  • Grid properties (cartesian grid, radial grid, corner point grid, etc.) & key elements to take into account
  • Time step management & main events to take into account
  • Petrophysics
  • Data review & petrophysical upscaling
  • Fluids
  • Data review & formalisms used by the simulator
  • Use of black oil data set & integration of lab experiments (constant composition expansion, constant volume depletion)
  • Initial state
  • Data review & formalisms used by the simulator (equilibration regions)
  • Identification of fluids in place per region
  • Aquifers representation and modeling
  • Formalisms used by the simulator (gridded or analytical aquifers)
  • Review of different possibilities (bottom, edge, transient, steady state, semi steady state) & “Hurst & Van Everdingen” tables
  • Flow Representation
  • Formalisms used by the simulator (transmissivity multipliers, end point scaling of capillary pressures & relative permeability)
  • Identification of production mechanisms & material balance analysis
  • Wells representation
  • Formalisms used by the simulator (Inflow Performance & numerical PI, outflow performance & VFP tables)
  • Practical exercise using the simulation software
  • History match
  • Objectives & methodology
  • Production data & identification of data to match
  • Production mechanisms & identification of matching parameters
  • History matching strategies (pressure, saturation, early & late times) & uncertainty reduction
  • Production forecast
  • Objectives & methodology
  • Integration of well representation & production constraints
  • Estimation of future productions linked to different scenarios and identification of remaining uncertainties
  • Identification of recommended scenario and conclusions
Part 2: Field development study 5 days
  • Field case presentation and critical analysis of the dataset
  • PVT data
  • Kr-Pc data
  • Accumulation
  • Analysis of various production schemes
  • Natural depletion down to bubble point, below bubble point, down to maintained optimum pressure
  • Water injection
  • History matching
  • Matching field pressure, wells pressure, water-cut and GOR
  • Select the matching parameters and related range
  • Decide on the level of acceptability of the history match
  • Production forecast
  • Using the selected previously matched dataset, perform a development study
  • Investigate natural depletion and water injection (and possibly WAG): optimize recovery adding producers, injectors, finding out their optimal location
  • Recommend an FDP based on relevant economic calculations (NPV, IRR, Profitability Index, etc.)