PETROPHYSICS Pty Ltd provides petrophysical training and consulting expertise to the oil and gas ind

  Under your feet is a reservoir.   We must answer two important questions about it. How much is HC? How easy will it flow? These petrophysical metrics tell us how much HC there is. Equivalent HC Column, feet, or metres. How easily it will come out, is Flow Capacity.   These are not averages, but accumulated values. It is the petrophysicist's job to measure these essentials as accurately as possible using all available means.   The petrophysicist has the best tools to accomplish this task than any other member of the team.   This is what I have done. Petrophysical EHC and Kh must be the absolute reference for these fundamental properties.   Any model that purports or attempts to describe a resource must have the first requirement equal to the Petroleum EHC And petrophysical kh At the well tracks.   Permeability averaging serves as a servant to this requirement and not the master.   Whatever method is used to calculate permeability, it must respect the reference at the well track.  

PETROPHYSICS Pty Ltd’s industry benchmark petrophysics training courses have been carefully converted to live Virtual Instructor Led Training (VILT).  Care has been taken to retain the full learning impact of the face-to-face originals with each course containing carefully sequenced Pre and Post Self Study Modules. The self study modules are delivered before and after the main, live VILT session so participants can prepare for and consolidate the learning experience.  Delivery mechanisms are deliberately varied and include short, focused instructor videos, selected texts and excercises, quizzes, micro-practicals, papers and industry videos.  Each module concludes with a live Question and Answer session and the instructor remains open to emailed questions and phone calls/video links throughout the three week period.  Lastly, updated course materials are available to all paid participants for a period of three years from the course start date. This extended VILT format is believed to be

 Because pore size is a factor in saturation and permeability, it seems logical to use saturation-related parameters to predict permeability. This is not possible in all geological or petrophysical models. We instead acquire NMR logs, core analyze flow zones, and rock types to attempt to use porosity for permeability variations. However, we ignore what we have in order to make a more accurate, cheaper prediction of permeability. The hydrocarbon pore volume is a better default prediction of intergranular permeability across different reservoir types, and different rock types than porosity and even saturation. Sw Swi should first be evaluated by fluid zones. Petrophysicists know that good rocks contain more hydrocarbons than poor rocks at the same capillary pressure (height). But they don't use it! For Saturation Height, Capillary Pressure Mercury Injection Data is (MCIP). Additionally, mercury data cannot be used to calculate Sw-Height in clayy, low-permeability rocks without Cation