This curriculum spans the technical workflow of a multi-year reservoir simulation effort, comparable to the iterative modeling cycles conducted during field development planning and EOR evaluation in major integrated oil companies.
Module 1: Reservoir Characterization and Geological Modeling
- Selecting appropriate grid resolution in geological models to balance computational feasibility with accurate representation of heterogeneity in faulted carbonate reservoirs.
- Integrating seismic inversion data with well log measurements to constrain porosity and permeability distributions in fluvial depositional systems.
- Handling uncertainty in fault transmissibility multipliers when structural data from seismic interpretation has limited resolution.
- Deciding between corner-point and Cartesian grid geometries based on structural complexity and simulator compatibility.
- Validating facies modeling outputs using borehole image logs and core data to ensure realistic connectivity of flow units.
- Managing upscaling of fine-scale petrophysical properties while preserving relative permeability and capillary pressure behavior at the simulation cell level.
Module 2: Fluid Property Definition and PVT Modeling
- Designing laboratory PVT sampling protocols that capture representative fluid composition under reservoir conditions for volatile oil systems.
- Selecting equation-of-state models (e.g., Peng-Robinson) and tuning them to match measured swelling and constant composition expansion tests.
- Handling compositional variation across reservoir compartments when defining black-oil versus compositional simulation approaches.
- Implementing saturation pressure checks during initialization to avoid phase inversion artifacts in low-pressure regions.
- Adjusting oil formation volume factor (Bo) and solution gas-oil ratio (Rs) for dissolved asphaltene effects in heavy oil reservoirs.
- Validating fluid property tables across pressure and temperature ranges encountered during production and gas injection scenarios.
Module 3: Initialization of Reservoir Simulation Models
- Establishing equilibrium initial conditions using capillary pressure curves and regional aquifer support data in structurally complex fields.
- Correcting non-physical pressure gradients caused by inconsistent depth datum alignment between seismic and well data.
- Assigning initial water saturation distributions based on core-calibrated log interpretations and transition zone models.
- Handling initialization of dual-porosity systems by balancing matrix-fracture fluid transfer under capillary and gravity forces.
- Addressing discrepancies between static formation pressures and dynamic well test data during model equilibration.
- Setting initial conditions for volatile oil or gas condensate systems where dew point pressure varies spatially.
Module 4: Well Modeling and Dynamic Boundary Conditions
- Configuring wellbore connectivity and skin factors for multilateral wells with varying completion types across intervals.
- Defining time-varying constraints for producers and injectors based on actual operational limits from field surveillance data.
- Implementing rate allocation factors in commingled production scenarios where individual zone contributions are unmeasured.
- Selecting between nodal analysis and fixed bottom-hole pressure constraints based on availability of well performance history.
- Modeling gas lift operations by specifying injection schedules and mandrel depths in vertical and deviated wells.
- Handling well control switching logic to reflect realistic operational responses to water breakthrough or facility constraints.
Module 5: Numerical Solution Strategies and Simulation Runtime Management
- Tuning linear solver tolerances and iteration limits to prevent false convergence in high-contrast permeability models.
- Adjusting time step controls to manage phase behavior instability during gas injection or pressure depletion events.
- Implementing local grid refinement (LGR) selectively around wells to capture near-wellbore dynamics without global cost increase.
- Choosing between fully implicit and sequential solution schemes based on fluid compressibility and mobility ratios.
- Monitoring simulation job progress on high-performance computing clusters and diagnosing stalled or divergent runs.
- Managing memory allocation for large-scale models by partitioning grids across distributed computing nodes.
Module 6: History Matching and Uncertainty Quantification
Module 7: Forecasting and Development Scenario Evaluation
- Defining economic and operational constraints for future well placement and phasing in long-term development plans.
- Simulating waterflood pattern optimization by varying injection rates and well conversions under facility limitations.
- Assessing gas-oil gravity drainage performance in fractured reservoirs under different drawdown strategies.
- Modeling infill drilling sequences and their impact on pressure support and sweep efficiency.
- Evaluating EOR methods such as WAG (water alternating gas) by configuring injection schedules and three-phase hysteresis models.
- Generating forecast ensembles that reflect both geological uncertainty and operational variability for decision support.
Module 8: Model Governance and Lifecycle Management
- Establishing version control protocols for simulation input files to track changes across multidisciplinary teams.
- Defining metadata standards for model documentation, including assumptions, data sources, and limitations.
- Coordinating updates to the simulation model following new well completions or significant production anomalies.
- Archiving simulation cases with sufficient context to enable future reinterpretation or regulatory audits.
- Implementing access controls and review gates for model modifications in shared asset environments.
- Aligning model update frequency with field development milestones to balance accuracy and resource allocation.