INTEGRATING LOG, CORE
& TEST DATA (A WORKSHOP)

Instructor: Roger L. Nutt                                                             5 days

 

Who should attend:

Petrophysicists, Geologists, Reservoir, Simulation and Petroleum Engineers with log analysis experience who need to obtain the maximum benefit from the available data.

 

About this course:

Well logs have become an indispensable tool for evaluating hydrocarbon reservoirs. But, taken alone, they are not the complete answer; indeed, they can sometimes be very misleading. This course will show you how to avoid the common errors in formation evaluation by collecting and integrating all the data you need into a reliable model of your reservoir. How can you identify ineffective porosity? Confronted by shaley sands, what’s the first question you should ask? Which shaley sand equation should you use? What does a karstic reservoir look like? How can it be evaluated? Is your value of porosity reliable? Is the water saturation correct? Can you be sure of your fluid contacts? The instructor uses clear and easy-to-understand Power-Point slides and loads of practical examples, livened with entertaining anecdotes from a lifetime's experience in the oil-patch.

 

Course Content:

• Fundamentals of open-hole log analysis.
• The right tools for the job.
• Determining porosity - available methods, what they measure, calibrating the logs, integration with core data.
• Determining effective porosity, compensation for hydrocarbon effects.
• Using R_o and R_wa
• Finding the right petrophysical parameters
• Checking S_w - capillary pressure, cased-hole logs, cores.
• Permeability and its distribution - how to measure it, how to predict it - logs, cores, tests and wireline pressure test methods.
• Defining the reservoir and establishing its properties.
• What information to collect, and how to collect it.
• Practical exercises in data integration

 

What you will learn...

Which tools to use to evaluate your reservoir, and what their limitations are. How to combine all the information – from all your wells – using methods which optimize the data you need to model your reservoir and estimate reserves: Porosity, Saturation, Net Pay, Permeability and Fluid Distribution. When you can use core data to calibrate your logs - and when you can't. You will work on examples from a wide variety of formation types – shaley sands, granular carbonates, karsts – from all over the world. You will learn how to use modern high-tech methods – FMS, MDT, NMR, LWD – and when they are a waste of time and money.