Exploration in Australia 2000–2010: reviewing a decade of growth

2011 ◽  
Vol 51 (1) ◽  
pp. 667
Author(s):  
Paul Rheinberg

Oil and gas exploration in Australia, both on and offshore, has been centred on a small number of proven petroleum provinces and—given the extent of prospective basinal area that exists—it remains relatively under-explored to this day. Since the 1970s, companies have progressively spent a smaller proportion of their exploration budgets on onshore and shallow water targets, where discoveries have been regular yet unspectacular, in favour of the deeper waters, where higher risks are involved but the potential exists for significantly higher returns. This activity has led to the discovery of more than of 150 Tcf of gas in the North Carnarvon, Browse and Bonaparte basins, the majority of which sits in deepwater areas. An absence of infrastructure and a lack of an adequate market meant that these huge discoveries lay undeveloped; however, with developments in technology and demand for gas in Asia set to surge into the next decade, these previously stranded fields are set to move into development, underpinning economic growth in Australia and ensuring that the country moves to the forefront of the LNG industry worldwide. This paper will examine upstream activity, both on and offshore, in Australia since 2000, a decade in which the country has become one of the most prominent destinations for exploration expenditure in the world. Following the exploration cycle from acreage release through to discovery, it will look at how trends and activity have changed over time and examine how successful the industry has actually been. It will explore the factors driving activity and the effects external forces such as regulatory changes, oil price and prevailing economic conditions have had on activity levels. No post-Conference paper is available for this presentation. No post-conference paper is available for this presentation.


2020 ◽  
Vol 39 (8) ◽  
pp. 558-565
Author(s):  
Balakrishnan Kunjan ◽  
Witan Ardjakusumah ◽  
Kevin McDonald ◽  
Hannah Booth ◽  
Seda Rouxel ◽  
...  

In all exploration processes, the evaluation of basins, permits, and individual prospects changes over time with incremental availability and quality of data, technical effort expended, and knowledge gained. The NU prospect, located in the Mahakam Hilir PSC (East Kalimantan), is an example in which geologic chance of success (GCOS) predictions can change over time with increasing acquisition and availability of geophysical and geologic data and the studies done on them. We show how studies done on any one prospect or group of prospects can progressively increase/decrease the chance of at least one success in an exploration campaign of several wells. After a series of four wells was drilled in the PSC, which did not deliver commercial success, a change in approach was required to continue exploration. This included the acquisition of airborne gravity gradiometry data, initial trial prestack depth migration (PSDM) reprocessing of two key 1989 vintage 2D lines, acquisition of vintage well data from four Sambutan Field wells, acquisition of nine vintage 2D seismic lines over the field, and PSDM reprocessing of the nine 2D seismic lines. All data were then integrated to build a new geologic model. As a result, the NU prospect GCOS progressively moved from less than 10% to nearly 40%.



Energies ◽  
2019 ◽  
Vol 12 (19) ◽  
pp. 3802
Author(s):  
Jun Li ◽  
Xiaoying Zhang ◽  
Bin Lu ◽  
Raheel Ahmed ◽  
Qian Zhang

Geological modelling is an important topic of oil and gas exploration and production. A new knowledge driven methodology of geological modelling is proposed to address the problem of “hard data” limitation and modelling efficiency of the conventional data driven methodology. Accordingly, a new geological modelling software (DMatlas) (V1.0, Dimue, Wuhan, China) has been developed adopting a grid-free, object-based methodology. Conceptual facies models can be created for various depositional environments (such as fluvial, delta and carbonates). The models can be built largely based on geologists’ understandings with “soft data” such as outcrops analysis and geological maps from public literatures. Basic structures (fault, folds, and discrete fracture network) can be easily constructed according to their main features. In this methodology, models can be shared and re-used by other modelers or projects. Large number of model templates help to improve the modelling work efficiency. To demonstrate the tool, two case studies of geological modelling with knowledge driven methodology are introduced: (1) Suizhong 36-1 field which is a delta depositional environment in Bohai basin, China; (2) a site of the north Oman fracture system. The case studies show the efficiency and reliability within the new methodology.



Polar Record ◽  
1961 ◽  
Vol 10 (67) ◽  
pp. 359-364
Author(s):  
A. T. Davidson

About 80 million acres on the mainland of the Northwest Territories and Yukon, and over 40 million acres on the Arctic islands, are under oil and gas exploration permit. Exploration permits were issued in the Arctic islands for the first time in June 1960, following promulgation in April of new Canada Oil and Gas Regulations for federal government lands. The issue of these permits extended the northern oil and gas search from the Alberta and British Columbia borders, in lat. 60° N., northward to the Arctic islands; in terms of land area this is one of the most widespread oil and gas searches in the world. The Arctic islands exploration also holds particular interest since it is the farthest north oil and gas exploration ever carried out.



2013 ◽  
Vol 448-453 ◽  
pp. 3723-3727 ◽  
Author(s):  
Yun Pan ◽  
Zong Xiu Wang ◽  
Mao Pan

There are a lot of Permian volcanic rocks which are widely distributed in Tarim Basin. Because of the shielding effect of the volcanic rocks to the underlying structure, the distribution of the volcanic rocks in Tarim Basin is very important to the deep oil and gas exploration. However, with the progress of oil exploration in Tarim oil field in recent years, much more logging and seismic data is available. Based on the model of logging-seismic integrated identification, the distribution of the Permian volcanic rocks is revised by using the drilling, logging and seismic data. It shows that the rhyolite is mainly distributed in the north basin, and the basalt is widely distributed in the basin. Moreover, the basalt has larger area than which delineated by other people.



1990 ◽  
Vol 50 (4) ◽  
pp. 877-902 ◽  
Author(s):  
David Greasley

A downward trend in British coal-mining productivity was reversed between the world wars. Declining productivity before 1914 was accompanied by wide regional differences, especially at the coalface. Scotland attained the best overall. productivity, while coalface productivity was highest in Durham and Northumberland. Regional differences narrowed by the 1920s but re-emerged in the 1930s, as mines in the North Midlands outpaced the productivity gains made elsewhere. Only a multifaceted interpretation can explain these distinctive patterns—over time, between regions, and at different stages of the coal-mining operation.



2021 ◽  
Vol 944 (1) ◽  
pp. 012004
Author(s):  
I A Sufajar ◽  
H M Manik ◽  
T B Nainggolan ◽  
D Kusnida

Abstract Gas hydrate is a physical compound composed of gas molecules that are formed in a seabed layer characterised by high pressure and low temperature. It is known as one of the alternative non-conventional hydrocarbons besides petroleum and natural gas. One of the identified areas of gas hydrate stability zone is in the North Bali Waters. The North Bali Waters is part of the North East Java Basin, which has oil and gas exploration and production, both conventional and non-conventional. One method of identifying the content of gas hydrates is by looking at the appearance of the Bottom Simulating Reflector (BSR) as shown on the Pre-Stack Time Migrated seismic sections. The detection of gas hydrate zone is determined by the presence of high amplitude, reversed polarity reflection and cross-cut reflection of sedimentary layer. This study aims to determine the existence of a BSR in the waters of North Bali. The procedures for analysing the existence of Bottom Simulating Reflector in this study are pre-processing, processing, and interpretation of 2D marine seismic data. The result shows gas hydrates found with indicated Bottom Simulating Reflector on CDP 35-812 at TWT depth of 1526-1582 ms, characterised by high amplitude-reverse polarity.



2019 ◽  
Vol 59 (1) ◽  
pp. 120
Author(s):  
Matthew Quinn

A country’s competitiveness as a destination to conduct oil and gas exploration and production operations can be assessed through analysis of key metrics including discovered volumes, new field wildcat success rate, average field size, discovered volumes per new field wildcat, fiscal terms, sanctity of contract, regulatory burden and civil society risk. When compared globally, Australia ranks very high for aboveground risk factors, well for discovered volumes and discovered volumes per new field wildcat but sits towards the lower end of the dataset for fiscal terms. When assigning each metric a score on a scale of 1–10 and appropriately weighting and combining them to produce one overall score for each country, Australia currently ranks fourteenth for offshore and sixth for onshore. Historically, Australia’s rankings have been relatively consistent and have not dropped below twentieth since 2006. Conducting this analysis at a basin level allows the introduction of ‘time to onstream’ and ‘yet to find’ as additional metrics. Of the Australian immature basins, the McArthur Basin has the highest ranking; and for moderately mature basins, the North Carnarvon Basin tops the list.



Geophysics ◽  
1962 ◽  
Vol 27 (1) ◽  
pp. 113-120
Author(s):  
Leo R. Newfarmer

A temporary oversupply of crude oil in the world has resulted in a decided reduction of exploration effort in North America. The term “temporary” usually refers to a shorter period of time than we are now facing, though, and the word “oversupply” seems inappropriate, too, when the vast world demand the next decade will produce is considered. It is proposed here to at-tempt an analysis of the situation which will enable us to forecast the reaction of industry management to this problem and, more particularly, to show what part the science of geophysics will have in future oil and gas exploration on this continent.



2019 ◽  
Vol 23 (2) ◽  
pp. 157-162 ◽  
Author(s):  
Jiatong Xie ◽  
Qirong Qin ◽  
Cunhui Fan ◽  
Dongfeng Hu ◽  
Hu Li

Tectonic fractures are a significant factor for production of the Longmaxi formation in Dingshan area. The analyse of the distribution and development degree of tectonic fractures is the main research method in present-day. Based on the data of field outcrops and borehole core, the new method-binary method is put forward by rock fracture and energy value to decide tectonic fracture development. According to the method the fitting formula is offered between the relation of the value of rock fracture, energy and the fracture density. Compared the fracture density predictive value and the observed value of 15 wells, all wells relative error less than 25%. The prediction results are accurate. According to the fitting formula of fracture development and distribution in the study area are obtained. The results show that the fracture density is high as a whole of the Longmaxi formation in Dingshan area. Whole shows by south east to gradually reduce the trend of the north west. Supported the future of the oil and gas exploration to provide geological basis and guidance in Dingshan area.





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