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Estimating thermal maturity in the Eagle Ford Shale petroleum system using gas gravity data

Gulf Coast Association of Geological Societies Transactions
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Abstract

Basin-wide datasets that provide information on the geochemical properties of petroleum systems, such as source rock quality, product composition, and thermal maturity, are often difficult to come by or assemble from publicly available data. When published studies are available and include these kinds of properties, they generally have few sampling locations and limited numbers and types of analyses. Therefore, production-related data and engineering parameters can provide useful proxies for geochemical properties that are often widely available across a play and in some states are reported in publicly available or commercial databases. Gas-oil ratios (GOR) can be calculated from instantaneous or cumulative production data and can be related to the source rock geochemical properties like kerogen type (Lewan and Henry, 1999) and thermal maturity (Tian et al., 2013; U.S. Energy Information Administration [EIA], 2014). Oil density or specific gravity (SG), often reported in American Petroleum Institute units (°API = 141.5 /SG – 131.5), can also provide information on source rock thermal maturity, particularly when combined with GOR values in unconventional petroleum systems (Nesheim, 2017).

Additional publication details

Publication type Article
Publication Subtype Journal Article
Title Estimating thermal maturity in the Eagle Ford Shale petroleum system using gas gravity data
Series title Gulf Coast Association of Geological Societies Transactions
Volume 67
Year Published 2017
Language English
Publisher Gulf Coast Association of Geological Societies
Contributing office(s) Central Energy Resources Science Center
Description 7 p.
First page 397
Last page 403