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The Arctic Ocean occupies a unique tectonic setting as a small, confined ocean between two much larger oceans - the subducting Pacific margin and the opening North Atlantic. Unlike many of the world's oceans, evidence on both timing and geometry is poor, and major elements of the plate tectonic evolution are still "up for grabs". The Arctic has experienced significant plate motion from Cretaceous to present, and because of the ambiguities in the oceanic signature, resolving the most likely kinematic history is critical in understanding paleogeography and hence reservoir and source distribution. I will show a 3-stage kinematic model which, while not a unique solution, seems to best satisfy the known constraints.

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The search for unconventional hydrocarbons is not new. It’s true that almost 100 years separated the early exploration successes in the synclinal valleys of Central Pennsylvania, to the exploitation of Coal-Bed Methane in a number of basins in the U.S. and Canada in the 1980’s. Since the 1980's, however, a quiet revolution began which by today has seen several waves of unconventional resources being pursued with economic success. Coal-bed methane was followed by the search for Center-Basin Gas, Shale Gas and most recently, Liquid-rich Shales (some of which aren't shales).

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The past 30+ years have witnessed a wide variety of exploration strategies and a number of technological “revolutions” in the search for oil and gas. Although the exploration landscape and tools of the trade are so different than they were in the early 1980’s, in one aspect we appear to have come full circle, realizing that a deep understanding of our basins is the critical element in any success.
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We have an unprecedented ability to realistically depict the spatial distributions of lithofacies in the subsurface thanks to developments in sequence stratigraphy, sedimentology, structural geology, geostatistics, and geophysics. As important as these developments have been, however, they in themselves have a limited ability to accurately predict rock properties–particularly in regions with high thermal exposures and restricted well control. We are developing a next-generation modeling platform that rigorously simulates processes in 3D at the grain scale. This 3D approach has the potential to provide unique predictive models of pore network geometries and grain contact properties for rocks in undrilled areas.

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Reservoir characterization is an exercise in constraining uncertainty that arises from sparse sampling of the subsurface by widely spaced wells at lengthscales below seismic resolution. Outcrop analogs are an invaluable complement to well and seismic data in this context, because they provide qualitative concepts and quantitative spatial data to guide interpretations of lithology distribution in inter-well volumes. However, analog-driven interpretations of reservoir architecture are not straightforward to compare with dynamic data that describe fluid flow during production – the acid test of any interpretation of reservoir geology. The value of outcrop reservoir analogs is most fully realized when they are used to construct outcrop-based reservoir models that enable explicit predictions of flow patterns in a form that can be compared with routine reservoir-monitoring data.

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I would like to suggest that far too much of the technical work purporting to guide exploration for petroleum is trivial, redundant and has little of use to offer toward finding new oil and gas accumulations. All geology is interesting; some geologic work is novel; damn little of the work we see is useful in finding new oil and gas fields!

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A crucial aspect of these fluid inclusions… is that they endure in the geologic record although the parent fluids move on. As a result, a given sample contains the fluid history of the area. In other words, despite being microscopic they’re jam-packed with information.

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23 April, 2015 23 April, 2015 16809 Desktop /Portals/0/PackFlashItemImages/WebReady/an-analytical-model-for-shale-gas-permeability-hero.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
 
23 April 2015
Recent laboratory studies have revealed previously unknown behaviors in shale gas which unlock secrets of permeability and sweet spots in shale gas reservoirs. The presentation presents the findings and also goes into detail about how the new information can be applied in order to potentially improve recovery in reservoirs.
02 December, 2014 02 December, 2014 11967 Desktop /Portals/0/PackFlashItemImages/WebReady/esymp-multiscale-modeling-of-gas-transport-hero.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
 
2 December 2014

The gas transport in organic-rich shales involves different length-scales, from organic and inorganic pores to macro- and macrofractures. In order to upscale the fluid transport from nanoscale (flow through nanopores) to larger scales (to micro- and macrofractures), multicontinuum methodology is planned to be used.

31 October, 2012 31 October, 2012 1492 Desktop /Portals/0/PackFlashItemImages/WebReady/oc-es-3-dimensional-approach-t-hydrocarbon-mapping.jpg?width=100&height=100&mode=crop&anchor=middlecenter&quality=75amp;encoder=freeimage&progressive=true
 
31 October 2012

This e-symposium will focus on how surface geochemical surveys and Downhole Geochemical Imaging technologies can be utilized jointly to directly characterize the composition of hydrocarbons vertically through the prospect section.

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