The Cretaceous source rocks from East Venezuela - Trinidad - Guyana/Suriname basins, NE South America Stratigraphy, biostratigraphy and geochemistry data of Cretaceous source rocks from Eastern Venezuela Basin, South Trinidad, Guyana.

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The Northeastern South American margin is defined by Eastern Venezuelan and Guyana Basins bound to the south by the Guayana Shield and Demerara Plateau. The Margin is emerging as a potential major petroleum province with recent discoveries made in the new play types in Guyana basin with a prolific Cenomanian-Turonian source rock and mostly clastic reservoirs of Cretaceous age. Hydrocarbon production from mostly clastic reservoirs exists in the Eastern Venezuelan Basin onshore for more than 100 years but there was no recent exploration activity offshore.

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Presented at First HGS/EAGE Conference on Latin America, November 2019 The existing perceptions of the offshore Uruguay petroleum system assessment may be challenged by an analysis of the failure modes of three exploration wells drilled in the basin. This is an underexplored basin with a poor exploration record. Arguably, the wells tested prospect-specific locations but left other plays of interest untested.

I think the biggest driver in oil price vulnerability is a human factor once again and people tend to overreact to the bad news. They do not take the time to take a step back and to look at a longer trend.

Steven Zobell in his article published by Forbes magazine in March of 2018 estimates that in 2018 enterprises will invest $1.3 trillion USD in Digital Transformation projects to “improve efficiencies, increase customer value and create new monetization opportunities”. In the same research, Steven analyses the reasons why 70% of these initiatives will not reach the objectives. AVGeo specialists were involved in digital workflow improvement projects in 2018 and would like to share our experiences and see if the predictions of Steve Zobell were correct.

In this presentation, I've discussed human cognitive learning while working with different sets of Big Data in Petroleum Exploration workflows. An effective reduction in the volumes of Big Data without information loss, AI in seismic interpretation and spatial analytics, and a visual aggregation of the single-threaded evaluations into a comprehensive multithreaded business decision are required for delivery of successful exploration programs

There is a renewed interest in exploration for oil and gas in deep and shallow waters of South Atlantic. The hopes are high especially with recent exploration success offshore Guyana and Mauritania. Delineation of the basins and mapping the extents of the pursued plays are two out of several critical components of the comprehensive geologic analysis and are fundamental to exploration success. During the last decade, deepwater drilling in South Atlantic proved multiple assumptions of the earlier geologic models of continent-ocean transition inadequate.

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The purpose of this study is to provide a pore pressure prediction from seismic data targeting unconventional gas plays (i.e., the Qusaiba Member hot shale and the underlying Sarah Formation). The area of interest (AOI) located in NW Saudi Arabia, and is covered by 1,600 km2 of 3D pre-stack time migrated (PSTM) data. The resulting pore pressure maps for the Qusaiba Member hot shale and Sarah Formation highlight potential drilling hazards. Importantly, areas of higher pore pressure may ultimately represent potential areas of higher gas production (i.e., sweet spots).