Applied Reservoir Petrophysics and Characterization (APRC) - Customized for Clients

This course can be customized to fit the needs of a client and be delivered as a traditional instructor lead class in either 5 or 7 days and alternatively as a remote instructor lead (RILS) class in 10 or 14 sessions.  Course participants make 6 to 7 presentations during APRC Course. It is common that workshops, case studies and group discussions account for 30 to 40% of the classroom time. The delivery schedule included in the description is an example, the actual contents can be adjusted for the client's specific purpose. 

• Day 1 -Overview of Geological Framework 
• Overview of Applied Petrophysical Quick Look Analysis Using Thin Sections for Carbonates and Clastics
• Overview of Lab based mineralogy (XRD and FTIR)
• Day 2 -Basic (Conventional) Core Analysis - Sample Preparation and Selection
• Determining bulk volume, pore volume and grain volume
• Determining net mean stress for core analysis measurements
• Core Porosity (Total and Effective)
• Introduce BCA - Permeability (How and Why)
• Day 3 -Introduce Petrophysical Rock Types, Facies and Capillary Pressure Concepts
• Define Free Water Level, Hydrocarbon water contacts, Irreducible water saturation and Height Above Free Water. 
• Define pore throat radius as determined in the lab based on mercury injection and predicted from empirical techniques (Winland, Pittman, K-PHI Ratio and Aguilera) 
• Day 4 -Introduce using statistical methods (CDF and Histograms) to determine petrophysical rock types (PRTs) for cores and logs
• Workshop - Defining Petrophysical rock types based on porosity and permeability
• Defining Pore Throat Radius and Petrophysical Rock Types in depth space for single wells
• Introduce FZI and RQI 
• Day 5 -Introduce the "3-Line Log Analysis quicklook analysis" - Method and Archie
• Introduce the Advanced Flow Unit Concept (4-Component Stratigraphic Modified Lorenz Plots and Modified Lorenz Plots as a key core-log integration technique)
• Introduce well test determined flow capacity, flow regime and well bore condition (skin)
• Day 6- Core-Log Integration and Using Mercury Injection Capillary Pressure Data to Confirm Petrophysical Rock Types, Pore Geometry and Clay effects
• Introduce the concept of Saturation Height Modeling to confirm petrophysical rock type and to evaluate free water level using capillary pressure and mercury injection data 
• Day 7- The importance of wettability and relative permeability for understanding reservoir performance and characterization 
• Workshop - relative permeability
• Final Workshop - Core-Log Petrophysical Well Evaluation and Presentation
• Participants complete a post course technical skills assessment (quiz)