Exploration in the Cooper Basin

Heath, R. S.

doi:10.1071/aj88031

Cited by 17 publications

(12 citation statements)

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“…During the Permian the basin was filled by a series of lacustrine and fluvial deposits. For a more complete discussion of the basin see Heath (1989).…”

Section: Regional Geology and Sample Descriptionmentioning

confidence: 99%

Geochemistry of aliphatic-rich coals in the Cooper Basin, Australia and Taranaki Basin, New Zealand: implications for the occurrence of potentially oil-generative coals

Curry

Emmett²,

Hunt³

1994

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Although the concentration of long-chain aliphatic constituents is a primary determinant of the oil generation potential of coals, the factors which govern their occurrence in different coals are poorly understood. In this study, Permian coals from the Cooper Basin, Australia, and the Eocene coals from the Taranaki Basin, New Zealand, were compared to determine these factors.The Taranaki Basin coals were deposited in temperate, fluvial-deltaic environments. HI values range from 236-365. Extracts have high pristane/phytane ratios and variable abundances of oleanane and other non-hopanoid terpanes. The extracts and pyrolysates contain high relative concentrations of aliphatic groups > n-C20. These data imply that much of this aliphatic carbon is derived directly from higher plant material.The Cooper Basin coals were deposited in high latitude bogs and contain 40-70% inertinite. The coals have been severel~¢ degraded. Pristane/phytane ratios are low (2.15-6), but His are moderate (up to 243 mg g-OC). The extracts and pyrolysates both contain high relative concentrations of aliphatic groups; however, the distributions are different from higher plant-derived material. These data imply the bulk of the aliphatic carbon in these coals is derived from microbial biomass (both bacterial and fungal degradation products and algal input).These results show that long-chain aliphatic groups in coals can be derived directly from the higher plant material, from microbial activity in the depositional environment, or from a combination of the two.

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“…During the Permian the basin was filled by a series of lacustrine and fluvial deposits. For a more complete discussion of the basin see Heath (1989).…”

Section: Regional Geology and Sample Descriptionmentioning

confidence: 99%

Geochemistry of aliphatic-rich coals in the Cooper Basin, Australia and Taranaki Basin, New Zealand: implications for the occurrence of potentially oil-generative coals

Curry

Emmett²,

Hunt³

1994

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“…4) The Cooper Basin is one of Australia's major gas and oil provinces. The main producing reservoirs in the Cooper Basin comprise sands from early Permian through to Triassic age 19 .…”

Section: Geologymentioning

confidence: 99%

Applications of Stress Field Modelling Using the Distinct Element Method for Petroleum Production

Camac

Hunt

2004

Proceedings of SPE Asia Pacific Oil and Gas Conference and Exhibition

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractThe distinct element method was first introduced in 1971 1 and has been progressively developed over the past two decades. It is described as a finite difference distinct element, numerical modelling method (DEM). The method was implemented in the computer program UDEC (2D and 3DEC (3D) 2 and its major application to date has been in the field of rock mechanics and mining engineering. In this paper we demonstrate the applicability of this method to the production of hydrocarbons.The method can be used to model 3D stress fields in a petroleum basin or field setting. It has been shown previously that stress field model data is consistent with actual borehole breakout data and hydro-fracturing measurements 3 . The modelling methodology can be used to calculate fluid potential and hence used to associate crustal stress, hydrocarbon migration and accumulation. By monitoring disturbances to the syn-production stress field estimation of the residual oil potential can be achieved.The work initially presents via sensitivity analysis the generic effect of faults and horizon boundaries on the mean local in-situ stress field. A case study is presented whereby the fault geometry for the Big Lake Field in the Cooper Basin of South Australia is modelled using DEM. Predictions of the spatial distribution of hydrocarbon accumulations and pressure gradients using the model were found to be accurate. Subsequently the model is adapted to account for production and the resultant pressure changes over time, which can lead to the prediction of residual hydrocarbon distributions.

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“…The synclinal areas contain up to 1300 m of Permian sediments overlain by as much as 2500 m of Jurassic to Tertiary strata (Battersby, 1976;Thornton, 1979). Fluvial sandstones, which occur at various levels within the Permian section, are the main petroleum reservoirs and include the fluvio-glacial Tirrawarra Sandstone (Smyth, 1979;Kantsler et al 1983;Heath, 1989;Hunt, Heath & Mckenzie, 1989;Yew & Mills, 1989). About 95 % of the Cooper Basin oil is reservoired in the Tirrawarra Sandstone of the Tirrawarra Field (Heath, 1989;Seggie et al 1994) (Fig.…”

mentioning

confidence: 98%

“…Up to 500 m erosion of sediments has been recognized in the southern parts of the basin (Kantsler et al 1983;Gray & Roberts, 1984), and although the effect diminished to the north, erosion is still evident in the study area. Deposition of Eromanga Basin sediments (JurassicCretaceous) commenced on the erosion surface of the Cooper Basin (Kantsler et al 1983;Heath, 1989). After a rapid subsidence which allowed deposition of the Cretaceous section, another tectonic event (T3) resulted in folding and faulting (Heath, 1989).…”

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confidence: 99%

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Tectonic fingerprints in siderite cement, Tirrawarra Sandstone, southern Cooper Basin, Australia

Rezaee

Lemon

Seggie³

1997

Geol. Mag.

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Compositional zoning and dissolution in cement is a direct response to the fluctuation of pore water chemistry, the variation of which during burial can be controlled by many factors, including the interaction between pore water and rock-forming minerals and the mixing of fluids from different origins. This paper suggests that tectonic activity can, by altering the hydraulic gradient, also influence pore water chemistry and lead to dissolution of cement, made clear by zoning within siderite crystals. Three different stages of siderite cement have been described from the Tirrawarra Sandstone in the Moorari and Fly Lake fields of the southern Cooper Basin, here referred to as S1 (early), S2 (middle), and S3 (late). Ragged dissolution surfaces separate the main phases, occurring after precipitation of S1 and S2 with incipient dissolution suggested within S2. Back-scattered electron (BSE) images and electron microprobe analyses clearly differentiate each main phase of siderite. S1 is a homogeneous, iron-rich siderite whereas S2 displays patchy compositional zoning associated with several minor dissolution stages, and S3 commences with even compositional banding and grades into a thick homogeneous phase in the terms of composition.Isotope analyses and fluid inclusion studies indicate that S1 formed at a temperature around 30 °C, S2 precipitated at a minimum temperature of 68 °C, and S3 formed around 102 °C. The heterogeneous, pitted and zoned S2 is thought to have formed during a time of active tectonism in the Cooper Basin, whereas the evenly banded nature of S3 suggests that it precipitated during a quiet tectonic period when pore waters largely remained relatively constant. It appears that siderite cements in the Tirrawarra Sandstone record tectonic activity in the form of irregular growth and dissolution highlighted by compositional zoning with stages of strong dissolution recording particularly active times when pore waters changed composition dramatically. Some zoning could be related in part to tectonic pulses. The temperature recorded by each of the siderite stages allows their precipitation to be tied to a burial history curve, and by making some simple assumptions about that history, the timing of cementation can be estimated. This can be an additional tool for calibrating the thermal history of an area.

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Exploration in the Cooper Basin

Cited by 17 publications

References 0 publications

Geochemistry of aliphatic-rich coals in the Cooper Basin, Australia and Taranaki Basin, New Zealand: implications for the occurrence of potentially oil-generative coals

Geochemistry of aliphatic-rich coals in the Cooper Basin, Australia and Taranaki Basin, New Zealand: implications for the occurrence of potentially oil-generative coals

Applications of Stress Field Modelling Using the Distinct Element Method for Petroleum Production

Tectonic fingerprints in siderite cement, Tirrawarra Sandstone, southern Cooper Basin, Australia

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