Restimulation Program Finds Success ICn Enhancing Recoverable Reserve

2000 ◽  
Author(s):  
John W. Ely ◽  
Robert Tiner ◽  
Mark Rothenberg ◽  
Anthony Krupa ◽  
Fred McDougal ◽  
...  
Keyword(s):  
Recoverable Reserve

BASS AND GIPPSLAND BASINS: A COMPARISON

1984 ◽  
Vol 24 (1) ◽  
pp. 101
Author(s):  
J. K. Davidson ◽  
G. J. Blackburn ◽  
K. C. Morrison
Keyword(s):  
Vertical Migration ◽  
Upper Cretaceous ◽  
Oil And Gas ◽  
Normal Fault ◽  
Gas Condensate ◽  
Normal Faults ◽  
Lower Eocene ◽  
Light Oil ◽  
Recoverable Reserve ◽  
Gippsland Basin

After two decades of exploration, one wireline test of oil, one of light oil and several of gas and gas/condensate have been recovered from the Bass Basin while the adjacent Gippsland Basin has established an estimated ultimate recoverable reserve of the order of half a billion kilolitres of liquids and a quarter of a trillion cubic metres of gas. Geologically, the basins are similar.The alluvial and nearshore deposits at the top of the Latrobe Group in Gippsland are as porous and permeable as similar deposits at the top of the Eastern View Group in Bass.The Eastern View and Latrobe Formations are regionally sealed by the Upper Eocene Demons Bluff and Oligocene Lakes Entrance Formations respectively. The intra-Latrobe section in Gippsland has significant but regionally not very extensive sealing units, whereas the Lower Eocene to Paleocene sequence in Bass is increasingly shale prone with depth, sometimes over-pressured, and constitutes an extensive seal for a base of Tertiary play. This play comprises Paleocene shales sealing Upper Cretaceous clastics with hydrocarbons potentially sourced from both units.Maturation studies (Saxby, 1980) indicate that the Upper Cretaceous is the principal source for hydrocarbons in Gippsland with possible lesser contributions from the Lower Paleocene and Lower Cretaceous. Limited data indicate the same is true in Bass and that the Paleocene and parts of the Lower Eocene are mature sources for gas/condensate and light oil. Normal faults assist vertical migration in Gippsland. In Bass, relatively few normal faults penetrate the Paleocene and Lower Eocene shales to reach the top of the Eastern View, greatly restricting the chances of vertical migration over much of the basin. Vertical migration is more likely beyond the margins of the depocentre.Eroded anticlines at the top of the Latrobe form large traps for the bulk of Gippsland's hydrocarbons. Small anticlines, wrench-related features and intra-Latrobe closures are more difficult to find. The normal fault blocks in Bass at the top of the Eastern View are wrench-modified and have proven difficult to define.The recent recognition in Bass of the base of Tertiary play and the need for careful structural and seismic interpretations is expected to lead to discoveries of oil and gas.

TECTONIC CONTROL OF WORLD OIL RESERVES: AUSTRALIA'S POSITION

1992 ◽  
Vol 32 (1) ◽  
pp. 183
Author(s):  
John K. Davidson
Keyword(s):  
Source Rocks ◽  
Continental Margins ◽  
Success Rates ◽  
North West ◽  
Oil Reserves ◽  
The North ◽  
Separation Result ◽  
Recoverable Reserve ◽  
Extreme Distribution ◽  
Former Ussr

Although simple extensional clay models may be representative of grabens tens of kilometres in length, rotational divergence of continents on a sphere produces very different structures. Repeated periods of compression during separation result in wrench faults and compressional anticlines developing along major crustal fractures as a consequence of changes in momentum between a continent and adjacent smaller continental blocks along its rifted margin.The global distribution of rotationally divergent continental margins can be accounted for by asymmetric expansion of the earth. The southern bulge caused by expansion has emphasised non-marine deposition on southern continents with marine deposition more common in the northern hemisphere.Phanerozoic source rocks of the northern hemisphere account for 97 per cent of the world's produced and current reserves of oil. Australia's share of this extreme distribution asymmetry is less than one half of one per cent, yet the country covers five per cent of the Earth's continental crust.The proportion of undiscovered oil reserves outside OPEC and the former USSR is approximately 30 per cent, or some 12 per cent of the world's estimated ultimately recoverable reserve of 2 trillion (Tera) barrels. The majority of Australia's undiscovered reserves lie on the North West Shelf where about 12 per cent of the country's estimated ultimately recoverable reserve could be found.Although Australia is politically stable, lower petroleum taxes would attract exploration for smaller, structurally complex oil fields. While such taxes may be considered politically difficult at present, a by-product of concerted oil exploration would be an enormous increase in Australia's gas reserves to feed the national pipeline grid for the 21st century. Industry can assist increased success rates by greater attention to current technical deficiencies, such as the structural interpretation of seismic lines.

3D microstructure characterisation of tight reservoir rocks and effective recoverable reserve estimation

2014 ◽  
Vol 54 (2) ◽  
pp. 539
Author(s):  
Sam Yang ◽  
Yudan Wang ◽  
Sherry Mayo ◽  
Andrew Tulloh ◽  
Keyu Liu ◽  
...  
Keyword(s):  
Rock Sample ◽  
Quantitative Relation ◽  
Pore Throat ◽  
Mineral Phase ◽  
Reserve Estimation ◽  
X Ray ◽  
Reservoir Rocks ◽  
3D Microstructure ◽  
Tight Reservoir ◽  
Recoverable Reserve

A data-constrained modelling (DCM) approach has been developed at CSIRO, which enables 3D characterisation of pores and mineral phase distributions using quantitative multi-energy synchrotron CT. For a tight reservoir, such as a carbonate limestone or a shale rock, DCM can generate microscopic partial volume distributions of materials and pores which are the effects of the fine length scales below X-ray CT resolution. Using this information, a quantitative relation between recoverable reserve and pore-throat size can be established for a rock sample. The technique can also be used for characterisation of other unconventional reservoir rocks.

THE ECONOMICS OF MARGINAL OFFSHORE OILFIELDS IN AUSTRALIA

1986 ◽  
Vol 26 (1) ◽  
pp. 67
Author(s):  
D.H. Heron ◽  
F.A. Jacobs
Keyword(s):  
Rate Of Return ◽  
Limiting Factor ◽  
Risk Capital ◽  
Resource Rent ◽  
Base Level ◽  
Self Sufficiency ◽  
Recoverable Reserve ◽  
The One ◽  
Offshore Development ◽  
Industry Needs

Australia's self sufficiency in oil will drop to below 50 per cent by the middle of the next decade unless major discoveries are made within the next few years. There is still a confusing series of permit regimes and fiscal frameworks applicable to exploration and development operations, and no indication of any upturn in offshore activity. If the decline in self sufficiency is to be halted, Industry needs to be assured that it will be allowed to operate under a simple unchanging set of rules such that it is guaranteed a fair return on its risk capital investment.There are many marginal oil discoveries which remain undeveloped for a variety of reasons, but the economics of their development must obviously be the one major limiting factor. A recoverable reserve of 15 million barrels of oil with peak production of about 8000 barrels of oil per day will in most instances provide a base development level with rate of return of 15 + per cent after tax. The new resource rent tax will have only a marginal impact on a development of this size, but the increasing impact of the resource rent tax as reserves and productivity increase above the base level will limit the rate of return on many marginal offshore discoveries to about 21 per cent.It is in marginal discoveries that there is a significant downside risk in development, and producers need to be assured of a reasonable risk loaded rate of return before committing to development. There are many ways of protecting operating companies from the relatively high risks of entering into a marginal offshore development. We have looked at only one of these and suggest that government might consider a lowering of the resource rent tax to 20 per cent for projects with reserves of less than 25 million barrels.

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