scholarly journals Towards direct detection of gold bearing rock formations from seismic data: St. Ives gold Camp, Western Australia

2008 ◽  
Author(s):  
Christopher Harrison ◽  
Milovan Urosevic
Keyword(s):  
Western Australia ◽  
Seismic Data ◽  
Direct Detection ◽  
Rock Formations ◽  
Gold Bearing

Combining Seismic Data from Passive and Active Sources for understanding the terrane structure of the Eastern Goldfields, Western Australia

2007 ◽  
Vol 2007 (1) ◽  
pp. 1-4
Author(s):  
Anya M. Reading ◽  
Erdinc Saygin ◽  
Brian L.N. Kennett ◽  
Bruce R. Goleby ◽  
Tanya Fomin ◽  
...  
Keyword(s):  
Western Australia ◽  
Seismic Data

THE HYDROCARBON POTENTIAL OF THE PENOLA TROUGH, OTWAY BASIN

1995 ◽  
Vol 35 (1) ◽  
pp. 358 ◽  
Author(s):  
R. Lovibond ◽  
R.J. Suttill ◽  
J.E. Skinner ◽  
A.N. Aburas
Keyword(s):  
Early Cretaceous ◽  
Seismic Data ◽  
Oil And Gas ◽  
Direct Detection ◽  
Source Rocks ◽  
Well Control ◽  
Potential Reservoir ◽  
Half Graben ◽  
History Of

The Penola Trough is an elongate, Late Jurassic to Early Cretaceous, NW-SE trending half graben filled mainly with synrift sediments of the Crayfish Group. Katnook-1 discovered gas in the basal Eumeralla Formation, but all commercial discoveries have been within the Crayfish Group, particularly the Pretty Hill Formation. Recent improvements in seismic data quality, in conjunction with additional well control, have greatly improved the understanding of the stratigraphy, structure and hydrocarbon prospectivity of the trough. Strati-graphic units within the Pretty Hill Formation are now mappable seismically. The maturity of potential source rocks within these deeper units has been modelled, and the distribution and quality of potential reservoir sands at several levels within the Crayfish Group have been studied using both well and seismic data. Evaluation of the structural history of the trough, the risk of a late carbon dioxide charge to traps, the direct detection of gas using seismic AVO analysis, and the petrophysical ambiguities recorded in wells has resulted in new insights. An important new play has been recognised on the northern flank of the Penola Trough: a gas and oil charge from mature source rocks directly overlying basement into a quartzose sand sequence referred to informally as the Sawpit Sandstone. This play was successfully tested in early 1994 by Wynn-1 which flowed both oil and gas during testing from the Sawpit Sandstone. In mid 1994, Haselgrove-1 discovered commercial quantities of gas in a tilted Pretty Hill Formation fault block adjacent to the Katnook Field. These recent discoveries enhance the prospectivity of the Penola Trough and of the Early Cretaceous sequence in the wider Otway Basin where these sediments are within reach of the drill.

Application of Structural Properties of Seismic Data to Prediction of Hydrocarbon Distribution

2018 ◽  
Vol 10 (3) ◽  
pp. 41-52
Author(s):  
Zhou Wei ◽  
Guo Haimin ◽  
Yaoting Lin
Keyword(s):  
Structural Properties ◽  
Seismic Data ◽  
Oil And Gas ◽  
Reservoir Prediction ◽  
Dispersed Oil ◽  
Rock Formations ◽  
Seismic Reservoir ◽  
Oil Concentration ◽  
Hydrocarbon Distribution ◽  
Seismic Data Structure

This article describes how under the influence of traps and trap ranges in size, final moisture content in oil production and changes in the reservoir is very large. Due to this, thin and dispersed oil concentration, facies changes and oil complexes, and strong segmentation, results in poor comparability between wells and conventional methods of seismic reservoir prediction has been more difficult to meet the development needs of the block. Therefore, the introduction of methods of seismic data structure characteristics, with a method based on sequence structure of underground rock formations, rock and petroleum allows the prediction for oil and gas purposes. Through the application of seismic structural properties, the result has been verified in practice and achieved a good application effect.

THE M. AUSTRALIS SANDSTONES, DAMPIER SUB-BASIN, AUSTRALIA

1999 ◽  
Vol 39 (1) ◽  
pp. 104
Author(s):  
A.J. Crowley
Keyword(s):  
Mass Flow ◽  
Western Australia ◽  
Seismic Data ◽  
Shelf Break ◽  
Oil Fields ◽  
Reservoir Quality ◽  
Flow Deposit ◽  
Basin Floor ◽  
A Minor ◽  
Maximum Flooding Surface

Three independent Barremian sandstone units that are characterised by the M. australis palynozone have been identified in the Lewis Trough and Enderby Terrace of the southeastern Dampier Sub-Basin, offshore Western Australia. They constitute a basin-floor fan unit and shelfal transgressive unit that are characterised by the lower Af. australis sub-zone, a shelfal marine to fluvial unit that is characterised by the middle M. australis sub- zone and a shelfal marine unit that is characterised by the upper M. australis sub-zone. The M. australis sandstones are characterised by their excellent reservoir quality, generally common to abundant glauconite content and common provenance.Core, wireline log and seismic data from wells in the Lewis Trough indicate the sediments characterised by the lower M. australis sub-zone form a mass-flow deposit on the regionally extensive Intra-Muderong Hiatus. Transgressive shelfal greensands, interpreted to lie within the latter part of the lower M. australis sub-zone overlie the In tra-Muderong Hiatus on the Enderby Terrace. The glauconitic sandstones characterised by the middle M. australis sub-zone were deposited during a relative highstand and overlie a maximum flooding surface identified in wells on the southern Enderby Terrace. These deposits form the reservoir section for the Wandoo and Stag oil fields. At Wandoo they form a series of seismically definable progrades, whereas at Stag they are the distal toe-sets that lie sub-parallel to the underlying surface. The subsequent sequence boundary is identified in wells and on seismic data as an erosional surface cutting the underlying sediments. Glauconite-rich, transgressive deposits form a fining-up sequence overlie the sequence boundary. Glauconitic sandstones characterised by the upper M. australis sub-zone were deposited at the palaeo- shelf break during a minor regression.

Regional Sn velocities and shear velocity in the upper mantle

1973 ◽  
Vol 63 (2) ◽  
pp. 469-475
Author(s):  
Stephen Huestis ◽  
Peter Molnar ◽  
Jack Oliver
Keyword(s):  
Shear Wave ◽  
Western Australia ◽  
Upper Mantle ◽  
Seismic Data ◽  
Shear Velocity ◽  
Apparent Velocity ◽  
Mantle Structure ◽  
Uppermost Mantle ◽  
Seismic Shear ◽  
Upper Mantle Structure

abstract Determinations by various authors of the apparent velocity of the seismic shear wave Sn, which propagates in the uppermost mantle, are presented for several of the Earth's stable regions. Measurements of the velocity over two additional shield areas, India and Western Australia, were made and gave values of 4.72±0.03 km/sec and 4.75-4.87 km/sec, respectively. In general, the Sn velocity is greater than 4.7 km/sec. As the stable regions cover most of the Earth's surface and this velocity is representative of the shear velocity in the uppermost mantle, it is useful as a constraint in inversion of seismic data to determine upper-mantle structure.

scholarly journals Instantaneous Attributes Applied to Full Waveform Sonic Log and Seismic Data in Integration of Elastic Properties of Shale Gas Formations in Poland

2018 ◽  
Vol 35 ◽  
pp. 03007 ◽  
Author(s):  
Kamila Wawrzyniak-Guz
Keyword(s):  
Shale Gas ◽  
Seismic Data ◽  
Seismic Survey ◽  
Reservoir Properties ◽  
Full Waveform ◽  
Rock Formations ◽  
Sonic Log ◽  
Geological Factors ◽  
Full Waveforms ◽  
Frequency Phase

Seismic attributes calculated from full waveform sonic log were proposed as a method that may enhance the interpretation the data acquired at log and seismic scales. Though attributes calculated in the study were the mathematical transformations of amplitude, frequency, phase or time of the acoustic full waveforms and seismic traces, they could be related to the geological factors and/or petrophysical properties of rock formations. Attributes calculated from acoustic full waveforms were combined with selected attributes obtained for seismic traces recorded in the vicinity of the borehole and with petrophysical parameters. Such relations may be helpful in elastic and reservoir properties estimation over the area covered by the seismic survey.

scholarly journals Multidisciplinary Characterization of Unconventional Reservoirs Based on Correlation of Well and Seismic Data

Energies ◽  
2020 ◽  
Vol 13 (17) ◽  
pp. 4413
Author(s):  
Weronika Kaczmarczyk ◽  
Małgorzata Słota-Valim
Keyword(s):  
Seismic Data ◽  
High Porosity ◽  
Reservoir Properties ◽  
Shale Formations ◽  
Petrophysical Parameters ◽  
Area Source ◽  
Shear Wave Velocities ◽  
Rock Formations ◽  
Fracture Susceptibility

Combinatorial analysis of key petrophysical parameters can provide valuable information about subsurface hydrocarbon reservoirs. This is particularly important for reservoirs with unconventional rock formations that, due to the low permeability, need to be stimulated by fracturing treatment to provide fluid flow to the exploitation wellbore. In this article, based on data from unconventional shale formations (N Poland), we outline how independent sets of elastic and petrophysical parameters and other reservoir features can be co-analyzed to estimate the fracture susceptibility of shale intervals, which are characterized by a high total organic carbon (TOC) content and high porosity. These features were determined by analysis of each horizon’s elastic and mineralogical brittleness index (BI). These two variants were calculated first in 1D; integrated with the seismic data and finally compared with other parameters such as acoustic impedance, ratio of compressional and shear wave velocities, porosity, and density; and then presented and analyzed using cross plots that highlighted the key relationships between them. The overall BI trends were similar in both horizontal and vertical directions. The highest BI values were observed in the southeast of the analyzed area (Source I) and in the southeast and northwest of the area (Source II). These results can form the basis for predictive modeling of reservoir properties aiding effective reservoir exploration.

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