DESCRIPTION
This course will provide a comprehensive methodology for well performance analysis, with specific focus on unconventional The approach combines the use of several powerful rate transient analysis tools and techniques. Students will use material balance, unconventional reservoir, analytical model and hybrid numerical model analyses during this 1 day Participants will learn how to:
Critically assess data quality and perform qualitative diagnostics on well production data
Identify reservoir flow regimes from rate/pressure response
Estimate reserves, OGIP/OOIP and drainage area
Determine well performance parameters
Recognize pressure dependent permeability
Identify optimization candidates, including re-fracturing
Forecast production, focusing on the inherent uncertainty in unconventional plays
Examine the practical aspects of rate transient analysis using examples
Note: This is an introductory software course designed to familiarize students with the features and functionality within the software. be presented, detailed theory and play-specific workflows are beyond the scope of this class.
TOPICS COVERED
An introduction to well performance analysis
Review the fundamentals of rate transient analysis
Learn the modern production analysis methodology
Compare the constant rate and constant pressure solutions for key equations
The transition from conventional to unconventional
Describe a horizontal well with multiple fractures
Define stimulated reservoir volume (SRV) and cross-sectional area to flow (Ac)
List the expected flow regimes for a horizontal multifrac well
Data diagnostic workflow
Navigate the Diagnostics tab
Use a typecurve to evaluate data validity
Filter data using automatic and manual methods
Identify expected flow regimes using typecurves
Reservoir interpretation
Determine contacted area from the flowing material balance
Identify first linear flow with the specialized plot
Estimate formation conductivity (Ac√k) and the time to end of linear flow (telf)
Evaluate SRV parameters, including permeability and fracture half-length
Modeling
History match data to confirm interpretation
Forecast future production, and compare with decline forecasts
Evaluate uncertainty with Monte-Carlo probabilistic methods
Advanced tools and methods
Recognize pressure dependent permeability and apply geomechanical methods
Apply adsorption to shale reservoirs
Interpret gas-condensate or volatile-oil reservoirs with modified black-oil analyses
Evaluate wells as re-fracturing candidates, or history match wells that have already been re-fractured
