Phase behavior

Equations of state; fluid sampling and laboratory PVT tests; prediction of phase behaviors and reservoir fluid properties; Tuning of EOS using experimental data and field application of fluid data in commercial simulators; a comparison of black oil and compositional models.

Condensate issues

Condensate formation and growth; critical condensate saturation, gravity drainage, residual trapped gas and condensate; condensate banking; and well remedial.

Reservoir Flow

Relative permeability measurement methods; single and two phase inertial factor estimation methods; water flood; relative permeability variations with velocity & interfacial tension due to coupling (capillary number) and inertial effects; mechanistic models of coupling; relative permeability correlations and calculations for use in simulators and using the next generation (universal) method.

Estimating volumes and production mechanisms

Material balance equations (gas in-place calculations and drive mechanism identification); high pressure and high temperature reservoirs, depletion for dry, wet and gas condensate systems; active aquifers and pressure maintenance (including gas injection).

Well issues

Steady state and pseudo-steady state flow equations; well productivity calculations; perforation and fracture characteristics and effective parameters; perforation and fracture design; estimation of skin for perforated, fractured, deviated and horizontal wells.

NeW-COIN

A demonstration of this in-house software which calculates near wellbore relative permeability accounting for coupling and inertia; and estimates gas condensate well productivity for various completion strategies.  

The course is designed for mid to senior level Reservoir and Production Engineers involved in the evaluation, planning and development of gas condensate reservoirs.

Day 1

• Summary of Basic Reservoir Engineering
• Relative permeability measurement methods
• Phase behavior of reservoir fluids
  
  

Day 2

• Equations of state
• Fluid sampling and laboratory PVT tests
• Prediction of phase behaviors and reservoir fluid properties
• Condensate formation and growth
• Critical condensate saturation, condensate banking, gravity drainage;
• Water flood
  
  

      Day 3

• Single and two phase inertial factor estimation methods.
• Relative permeability variations with velocity & interfacial tension due to coupling (capillary number) and inertial effects.
• Mechanistic models of coupling.

• Relative permeability correlations and calculations for use in simulators and using the next generation (universal) method.
• Steady state and pseudo-steady state flow equations.
• Material balance equations.
• Depletion for dry, wet and gas condensate systems.
• Active aquifers and pressure maintenance.
• High pressure and high temperature reservoirs.
  
  

Day 4

• Perforation and fracture characteristics and effective parameters.
• Perforation and fracture design.
• Estimation of skin for perforated, fractured, deviated and horizontal wells.
  
  

Day 5

• Well productivity calculations.
• NeW-COIN demonstration.
• Field application of fluid data in commercial simulators. 

CDGA attendance certificate will be issued to all attendees completing minimum of 80% of the total course duration.