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Published byDylon Payne Modified about 1 year ago

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Tim Armitage

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Shale Gas Reservoir's The problems with Shale Reservoirs What is needed to Create a usable model Possible solutions to Porosity calculations Total Gas in place Pore connectivity Sweet spots Sensitivity analysis Conclusion

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Shale Gas Reservoir's need to contain kerogen

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No established database of key well data Heterogeneous reservoir conditions create the need for multiple calculations of total gas in place Kerogen: Gas storage Micro fractures: core sample analysis

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Spontaneous Potential logs, Pressure, temperature, resistivity, gamma ray, neutron, sonic and density. X-ray diffraction, X-ray fluorescence, fluid extraction, Nuclear magnetic resonance, Pyrolysis, and Pulse decay permeability readings from Core sampels.

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The equation below represents the relationship between total porosity and the many different density’s of the various shale gas components

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Tabel 3 shows the variation in calculations due to the need for exact values of the density of kerogen.

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Each reservoir zone needs its own set of average parameters. based on well specific core log data Then the gas in place calculation can be used

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Nanopores- kerogin and intergranular shale Micropores - intergranular shale Macropores – “cleaner units of the reservoir” Natural fractures

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Low water saturation with high TOC content Low clay content Higher porosity Higher interparticle permeability Low fracture initiation pressure

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Key parameters that have the greatest impact on the estimation of gas in place, productivity and hydraulic fracture design

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