Seismic Attributes for Resource Play

Satinder Chopra

Instructor: Satinder Chopra
Date: November 07 - 08, 2018
Duration: 2 days
Members (early bird/price): CAD$ 800/1000 (plus GST)
Non-members (early bird/price): CAD$ 900/1100 (plus GST)
Location: TBA
Time: TBA


Satinder Chopra has 34 years of experience as a geophysicist specializing in processing, reprocessing, special processing and interactive interpretation of seismic data. He has rich experience in processing various types of data like VSP, well log data, seismic data, etc, as well as excellent communication skills, as evidenced by the several presentations and talks delivered and books, reports, and papers written. He has been the 2010/11 CSEG Distinguished Lecturer, the 2011/12 AAPG/SEG Distinguished Lecturer and the 2014/15 EAGE e-Distinguished Lecturer. His research interests focus on techniques that are aimed at characterization of reservoirs. He has published 8 books and more than 400 papers and abstracts and likes to make presentations at any beckoning opportunity. His work and presentations have won several awards, the most notable ones being the EAGE Honorary Membership (2017), CSEG Symposium Honoree (2017), CSEG Honorary Membership (2014) and Meritorious Service (2005) Awards, 2014 APEGA Frank Spragins Award, the 2010 AAPG George Matson Award and the 2013 AAPG Jules Braunstein Award, SEG Best Poster Awards (2014,2007), CSEG Best Luncheon Talk award (2007, 2002) and several others. He is a member of SEG, CSEG, CSPG, EAGE, AAPG, and APEGA (Association of Professional Engineers, Geoscientists of Alberta).


Seismic attributes are routinely used to map seismic geomorphology and reservoir quality. With the more recent focus on unconventional resource plays, seismic attributes are also being used to evaluate reservoir and completion qualities. Geometric attributes such as coherence and curvature are invaluable in identifying geohazards from 3D seismic data. Curvature and reflector rotation are direct measures of strain, which along with thickness and lithology control the location and intensity of natural fractures. Prestack inversion for Young’s modulus and Poisson’s ratio (or equivalently for λρ and µρ) can be used (when calibrated against core and ECS logs) to estimate TOC and “brittleness”. A more quantitative estimate of brittleness and completion quality requires the use of microseismic and production log data. Velocity and amplitude anisotropy, calibrated against image logs and microseismic data provide measurements of open natural fractures and the present-day direction of maximum horizontal stress that can be used to guide the placement of lateral wells.

In this course, we will gain an intuitive understanding of the kinds of seismic features identified by 3D seismic attributes, the sensitivity of seismic attributes to seismic acquisition and processing, and of how ‘independent’ seismic attributes are coupled through geology. Attributes are only as good as the data that goes into them. For this reason, I will also address components of seismic acquisition, reprocessing, and data conditioning. I will review a sufficient amount of theory for inversion, bandwidth extension, cluster analysis, and neural networks to elicit the implicit assumptions made using this these technologies. Advanced knowledge of seismic theory is not required; this course focuses on understanding and practice.

Concepts and algorithm description will be general, but workflows will be illustrated through application to the Duvernay, Montney, Woodford, Utica, Bone Spring and Vaca Muerta shale resource plays.