About This Item
- Full TextFull Text(subscription required)
- Pay-Per-View PurchasePay-Per-View
Purchase Options Explain
Share This Item
The AAPG/Datapages Combined Publications Database
AAPG Bulletin
Abstract
AAPG Bulletin, V.
Hydrocarbon
Generation in Two Petroleum Systems of the Taroom Trough, Australia
1Manuscript received August 7, 1996; revised manuscript received
September 2, 1997; final acceptance February 25, 1998.
2Organic Geochemistry in Basin Analysis Group, Department
of Geology and Geophysics, The University of Adelaide, S.A. 5005, Australia.
Present address: School of Earth Sciences, Macquarie University, N.S.W.
2109, Australia.
3Australian Geological Survey Organisation, G.P.O. Box 378,
Canberra, ACT 2601, Australia.
4Organic Geochemistry in Basin Analysis Group, Department
of Geology and Geophysics, The University of Adelaide, S.A. 5005, Australia.
5National Centre for Petroleum Geology and Geophysics, The
University of Adelaide, S.A. 5005, Australia.
This study represents part of Al Arouris doctoral research, supported
by an Australian Postgraduate Award (OPRS) and an Adelaide University Postgraduate
Research Scholarship. We are grateful to P. Green (Geological Survey of
Queensland) for samples and data. The Australian Geo logical Survey Organisation
is also thanked for making available its isotope and organic geochemistry
facilities during the course of this study. P. Tingate (National Centre
for Petroleum Geology and Geophysics) helped with BasinMod®
computing and stimulating discussions. Constructive reviews by W. G. Dow
and L. B. Magoon improved the manuscript and are highly appreciated.
ABSTRACT
Thermal maturity modeling, using first-order reaction kinetics, of
a Permian and a Triassic source rock in the Taroom trough was employed
to determine the time over which petroleum generation, migration
, and
accumulation
occurred, and to explain the observed distribution of oil and gas. Modeling
shows that the maximum paleotemperatures were attained in these two source
rock units by burial at the south end of the Taroom trough during the Late
Cretaceous. In the north, maximum paleotemperatures were caused by increased
heat flow, as well as burial to maximum depth. In the southern part of
the study area, the Permian-Triassic source rocks started expelling hydrocarbons
during the Jurassic-Early Cretaceous. These hydrocarbons migrated updip
to the east and west where structural-stratigraphic traps had formed in
response to Triassic compressional deformation. Kinetic modeling supports
biomarker and other geochemical evidence that the oil and gas currently
produced from sandstone reservoirs were sourced mainly from the carbonaceous
shales of the Upper Permian Blackwater Group.
Hydrocarbon
output from the
Middle Triassic Snake Creek Mudstone was minor, but sufficient to produce
a second petroleum system. North of the study area, early (Triassic) generation
of hydrocarbons and subsequent (Jurassic-Cretaceous) burial resulted in
an overmature Permian section, at present able to generate only dry gas.
The bulk of its hydrocarbons most likely have seeped to the surface. Only
late-mature
expulsion
products, which subsequently migrated southward,
could have contributed to the petroleum reserves of the region.
Pay-Per-View Purchase Options
The article is available through a document delivery service. Explain these Purchase Options.
Watermarked PDF Document: $14 | |
Open PDF Document: $24 |
AAPG Member?
Please login with your Member username and password.
Members of AAPG receive access to the full AAPG Bulletin Archives as part of their membership. For more information, contact the AAPG Membership Department at [email protected].