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[资料贴] Shale Resource Systems for Oil and Gas: Part 2—Shale-oil Resource Systems

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    Success in shale-gas resource systems has renewed interest in efforts to attempt
    to produce oil from organic-rich mudstones or juxtaposed lithofacies
    as reservoir rocks. The economic value of petroleum liquids is greater than
    that of natural gas; thus, efforts to move from gas into more liquid-rich and blackoil
    areas have been another United States exploration and production paradigm
    shift since about 2008.
    Shale-oil resource systems are organic-rich mudstones that have generated
    oil that is stored in the organic-rich mudstone intervals or migrated into juxtaposed,
    continuous organic-lean intervals. This definition includes not only the
    organic-rich mudstone or shale itself, but also those systems with juxtaposed
    (overlying, underlying, or interbedded) organic-lean rocks, such as carbonates.
    Systems such as the Bakken and Niobrara formations with juxtaposed organic-lean
    units to organic-rich source rocks are considered part of the sameshale-oil resource
    system. Thus, these systems may include primary and secondary migrated oil. Oil
    that has undergone tertiary migration to nonjuxtaposed reservoirs is part of a
    petroleum system, but not a shale-oil resource system.
    A very basic approach for classifying shale-oil resource systems by their
    dominant organic and lithologic characteristics is (1) organic-rich mudstones
    with predominantly healed fractures, if any; (2) organic-richmudstones with open
    fractures; and (3) hybrid systems with a combination of juxtaposed organic-rich
    and organic-lean intervals. Some overlap certainly exists among these systems,
    but this basic classification scheme does provide an indication of the expected
    range of production success given current knowledge and technologies for
    inducing these systems to flow petroleum.
    Potential producibility of oil is indicated by a simple geochemical ratio that
    normalizes oil content to total organic carbon (TOC) referred to as the oil saturation
    index (OSI). The OSI is simply an oil crossover effect described as when
    petroleum content exceeds more than 100 mg oil/g TOC. Absolute oil yields do not provide an indication of this potential for production as oil content tends to
    increase as a natural part of thermal maturation. Furthermore, a sorption effect
    exists whereby oil is retained by organic carbon. It is postulated that as much as 70
    to 80 mg oil/g TOC is retained by organic-rich source rocks, thereby limiting producibility
    in the absence of open fractures or enhanced permeability. At higher
    maturity, of course, this oil is cracked to gas, explaining the high volume of gas in
    various shale-gas resource systems. Organic-lean rocks, such as carbonates, sands,
    or silts, may have much lower oil contents, but only limited retention of oil as
    these rocks havemuch lower sorptive capacity. The presence of organic-lean facies or
    occurrence of an open-fracture network reducethe importanceof thesorptioneffect.
    The oil crossover effect is demonstrated by examples from organic-rich but
    fractured Monterey, Bazhenov, and Bakken shales; organic-rich but ultra-lowpermeability
    mudstone systems, such as the Barnett and Tuscaloosa shales; and
    hybrid systems, such as the Bakken Formation, Niobrara Shale, and Eagle Ford
    Shale, as well as Toarcian Shale and carbonates in the Paris Basin.

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    [LV.10]以坛为家III

    发表于 2013-1-3 15:23:45 | 显示全部楼层
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