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Enhanced Oil Recovery in Oil Drilling

Enhanced Oil Recovery in Oil Drilling

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This curriculum spans the technical, operational, and regulatory dimensions of EOR projects with a level of detail comparable to multi-phase field development planning, integrating subsurface analysis, facility design, real-time monitoring, and compliance workflows typical of integrated asset team engagements in major oil-producing basins.

Module 1: Reservoir Characterization for EOR Screening

  • Select appropriate reservoir rock typing methods to differentiate between high and low permeability zones affecting EOR injectant distribution.
  • Evaluate core sample data to determine residual oil saturation post-primary and secondary recovery for candidate selection.
  • Integrate 3D seismic attributes with well log data to map heterogeneity and identify bypassed oil zones.
  • Assess reservoir temperature, pressure, and salinity profiles to determine compatibility with thermal or chemical EOR methods.
  • Compare relative permeability curves under varying wettability conditions to predict displacement efficiency.
  • Apply screening criteria matrices to eliminate technically infeasible EOR methods based on API gravity, depth, and reservoir continuity.

Module 2: Thermal EOR: Steam Injection Design and Execution

  • Size steam generators and distribution manifolds based on required injection rates and downhole steam quality targets.
  • Model heat loss in injection tubing using nodal analysis to maintain desired steam quality at the reservoir face.
  • Design cyclic steam stimulation (CSS) soak periods based on thermal diffusivity and thermal communication between wells.
  • Monitor chamber development in SAGD operations using downhole temperature arrays and adjust well pair injection rates accordingly.
  • Manage sand production risks during steam injection by optimizing drawdown and installing downhole sand control.
  • Address surface subsidence risks by integrating geomechanical modeling with injection pressure management.

Module 3: Chemical EOR: Polymer, Surfactant, and Alkali Systems

  • Conduct core flood tests to determine optimal polymer molecular weight and concentration for mobility control.
  • Design surfactant formulations that achieve ultra-low interfacial tension without causing emulsion blockages in the near-wellbore.
  • Assess polymer shear degradation in surface injection lines and downhole safety valves to maintain viscosity.
  • Implement preflush designs in alkaline-surfactant-polymer (ASP) floods to mitigate scaling and incompatibility with formation brine.
  • Size surface chemical mixing and injection facilities based on slug volume and injection duration.
  • Monitor produced fluid chemistry to detect early surfactant breakthrough and adjust injection strategy.

Module 4: Gas Injection and Miscible Flooding Techniques

  • Perform slim tube tests to determine minimum miscibility pressure (MMP) for CO₂ or hydrocarbon gas injection.
  • Design injection well completions to minimize gas coning and early breakthrough in gravity-stable floods.
  • Allocate available gas supply between injection wells based on reservoir pressure support and sweep efficiency goals.
  • Implement downhole gas lift integration when using produced gas for re-injection in mature fields.
  • Model asphaltene precipitation risks during gas injection and implement inhibitor squeeze programs if needed.
  • Use tracer studies to evaluate interwell connectivity and identify unswept zones during WAG (Water Alternating Gas) cycles.

Module 5: Reservoir Simulation and EOR Performance Forecasting

  • Upscale fine-scale geological models to simulation grids while preserving key flow barriers and conduits.
  • Calibrate relative permeability hysteresis models for cyclic injection processes like CSS or WAG.
  • Define economic constraints in simulation runs, including maximum water cut and minimum oil rate thresholds.
  • Run history matching on waterflood performance before initiating EOR to validate base-case model accuracy.
  • Assess uncertainty in oil recovery forecasts using Monte Carlo simulations with probabilistic input parameters.
  • Optimize injection rate schedules using automated assisted history matching and production optimization tools.

Module 6: Well Design, Completion, and Injection Infrastructure

  • Specify high-temperature casing and cement formulations for steam injection wells to prevent casing collapse.
  • Design dual-string completions for SAGD well pairs to independently control injection and production.
  • Install downhole pressure and temperature gauges (DPTs) for real-time monitoring of flood front progression.
  • Size surface pipeline networks for high-volume polymer or CO₂ injection with corrosion-resistant materials.
  • Implement intelligent completions with interval control valves to manage conformance in heterogeneous zones.
  • Plan workover strategies for injector wells prone to scaling or plugging in chemical flooding operations.

Module 7: Monitoring, Surveillance, and Data Integration

  • Deploy time-lapse (4D) seismic surveys to track steam chamber or gas front expansion and adjust well placement.
  • Analyze produced fluid tracers to quantify sweep efficiency and identify early breakthrough pathways.
  • Integrate downhole sensor data with surface facility measurements for real-time injection allocation decisions.
  • Use fiber-optic DTS (Distributed Temperature Sensing) to detect steam entry zones and channeling in horizontal wells.
  • Establish baseline and ongoing water cut and GOR monitoring to detect loss of conformance.
  • Implement data validation protocols to ensure accuracy of injection volume and pressure records for audit and compliance.

Module 8: Environmental, Regulatory, and Project Economics

  • Design CO₂ capture and compression systems to meet pipeline quality specifications for injection.
  • Obtain Class II UIC (Underground Injection Control) permits for EOR operations involving CO₂ or chemical fluids.
  • Quantify greenhouse gas emissions from steam generation and offset via carbon sequestration credits.
  • Conduct water sourcing and disposal assessments for polymer floods requiring large volumes of clean water.
  • Model project economics using discounted cash flow analysis with oil price and operational cost sensitivities.
  • Develop contingency plans for EOR suspension due to regulatory changes or prolonged low oil prices.
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