VITRINITE PALAEOTHERMOMETRY OF OFFSHORE EXPLORATION WELLS, TASMANIA

1989 ◽  
Vol 29 (1) ◽  
pp. 130
Author(s):  
P.W. Baillie ◽  
N.J. Russell
Keyword(s):  
Sedimentary Basins ◽  
Computer Programs ◽  
Petroleum Exploration ◽  
Geothermal Gradients ◽  
Bottom Hole ◽  
History Of ◽  
Reflectivity Data ◽  
Temperature Time ◽  
Heating Duration ◽  
Offshore Petroleum

Over the last three decades organic metamorphism (coalification), as indicated by changes in vitrinite reflectivity, has been regarded as a function of both temperature and heating duration. This temperature- time concept of coalification has been developed into sophisticated computer programs to model the palaeo- geothermal history of sedimentary basins. However, several papers, published over the last six years, have presented evidence to support the view that, for heating times in excess of 0.001- 1 Ma, vitrinite reflectivity constitutes an absolute palaeogeothermometer. This proposition is broadly supported by a comparison between corrected bottom- hole temperature (BHT) and vitrinite reflectivity data from offshore petroleum exploration wells drilled in Tasmanian waters. Most of the corrected BHT/vitrinite reflectivity data pairs plot on, adjacent to or between two of the published vitrinite temperature/reflectance trends. Although these data indicate that some formations are at, or near, maximum palaeotemperature, there is clear evidence to suggest that many samples, in particular those from formations in the deeper well sections, have cooled significantly below maximum palaeotemperature. It appears that present- day geothermal gradients for some of the wells, based on corrected BHT data, are much less than maximum palaeogeothermal gradients inferred from the vitrinite depth/reflectance relationship.

scholarly journals Potential for the Geological Storage of CO2 in the Croatian Part of the Adriatic Offshore

Minerals ◽  
2019 ◽  
Vol 9 (10) ◽  
pp. 577 ◽  
Author(s):  
Bruno Saftić ◽  
Iva Kolenković Močilac ◽  
Marko Cvetković ◽  
Domagoj Vulin ◽  
Josipa Velić ◽  
...  
Keyword(s):  
Pannonian Basin ◽  
Sedimentary Basins ◽  
Petroleum Exploration ◽  
Geological Storage ◽  
Reservoir Properties ◽  
Secondary Porosity ◽  
Deep Saline Aquifer ◽  
Total Potential ◽  
History Of ◽  
Gas Fields

Every country with a history of petroleum exploration has acquired geological knowledge of its sedimentary basins and might therefore make use of a newly emerging resource—as there is the potential to decarbonise energy and industry sectors by geological storage of CO2. To reduce its greenhouse gas emissions and contribute to meeting the Paris agreement targets, Croatia should map this potential. The most prospective region is the SW corner of the Pannonian basin, but there are also offshore opportunities in the Northern and Central Adriatic. Three “geological storage plays” are suggested for detailed exploration in this province. Firstly, there are three small gas fields (Ida, Ika and Marica) with Pliocene and Pleistocene reservoirs suitable for storage and they can be considered as the first option, but only upon expected end of production. Secondly, there are Miocene sediments in the Dugi otok basin whose potential is assessed herein as a regional deep saline aquifer. The third option would be to direct future exploration to anticlines composed of carbonate rocks with primary and secondary porosity, covered with impermeable Miocene to Holocene clastic sediments. Five closed structures of this type were contoured with a large total potential, but data on their reservoir properties allow only theoretical storage capacity estimates at this stage.

Review of the 2008 offshore petroleum exploration release areas

2008 ◽  
Vol 48 (1) ◽  
pp. 359
Author(s):  
Marita Bradshaw
Keyword(s):  
Shallow Water ◽  
Sedimentary Basins ◽  
Water Area ◽  
Petroleum Exploration ◽  
Adjacent Area ◽  
Petroleum Potential ◽  
North West ◽  
The North ◽  
Wide Range ◽  
Offshore Petroleum

Each year the Australian Government releases new offshore opportunities for petroleum exploration. Thirty-five new exploration areas located across five of Australia’s offshore sedimentary basins are offered in the 2008 Release. All the areas are available through a work program bidding system with closing dates for bids at six and 12 months from the date of release. Acreage in the first round closes on 9 October 2008 and includes the more explored areas. The second closing round on 9 April 2009 comprises acreage located in less well explored and frontier regions. The 2008 exploration areas are in Commonwealth waters offshore of Western Australia and the Northern Territory, and in the Territory of the Ashmore and Cartier Islands adjacent area. The 2008 Release focusses on the North West Shelf, as well as offering two new exploration areas in the Vlaming Sub-basin in the offshore Perth Basin. Seven of the new release areas are located in Australia’s major hydrocarbon producing province, the Carnarvon Basin. They include a shallow water area in the western Barrow Sub-basin and another on the Rankin Platform, three areas in deeper water in the Exmouth Sub-basin and two on the deepwater Exmouth Plateau. Six areas are available for bidding in the Browse Basin and another five in the Bedout Sub-basin of the Roebuck Basin. In the Bonaparte Basin, the 15 Release areas are located in shallow water and represent a range of geological settings, including the Vulcan and Petrel sub-basins, Ashmore Platform and Londonderry High. The 2008 Offshore Petroleum Exploration Release of 35 areas in five basins covers a wide range in size, water depth and exploration maturity to provide investment opportunities suited to both small and large explorers. The Release areas are selected from nominations from industry, the States and Territory, and Geoscience Australia. The focus of the 2008 Release is on the North West Shelf where there is strong industry interest in the producing Carnarvon and Bonaparte basins and in the Browse Basin, the home of super-giant gas fields under active consideration for development. Also included in the 2008 Release is the Bedout Sub-basin, in the Roebuck Basin, located on the central North West Shelf, between the hotly contested Carnarvon and Browse basins. In addition, the Release show-cases the southern Vlaming Sub-basin, Perth Basin, where recent studies by Geoscience Australia provide a new understanding of petroleum potential (Nicholson et al, this volume).

Tunisian geothermal data from oil wells

Geophysics ◽  
1988 ◽  
Vol 53 (11) ◽  
pp. 1479-1487 ◽  
Author(s):  
Hamed Ben Dhia
Keyword(s):  
Steady State ◽  
Statistical Method ◽  
Empirical Relation ◽  
Geothermal Gradient ◽  
Petroleum Exploration ◽  
Formation Temperature ◽  
Geothermal Gradients ◽  
Drill Stem ◽  
Bottom Hole ◽  
Direct Measurements

Since direct measurements of steady‐state temperatures are not readily available in Tunisia, a geothermal investigation has been made using 1319 values of bottom‐hole temperatures (BHTs) obtained from 217 petroleum exploration wells. An empirical relation based on the differences between BHT and DST (drill stem tests) was used to correct BHTs and estimate geothermal gradients. The estimated geothermal gradient of the country varies between 21 and 52 °C/km. A few regions with similar gradients have been identified, and similarities between gradient contours and the main structural directions are noted. Furthermore, for 25 points from 12 wells, it was possible to apply the Horner‐plot method to determine the equilibrium formation temperature (Tf). Comparison of Tf values with those calculated by the estimated gradients reveals a good correlation (r = 97 percent) between the two estimates. This agreement permits greater confidence in the statistical method used and consequently in the estimated gradients for the whole country.

Sedimentary Basins and Petroleum Exploration in Japan: ABSTRACT

AAPG Bulletin ◽  
1962 ◽  
Vol 46 ◽  
Author(s):  
Helen L. Foster
Keyword(s):  
Sedimentary Basins ◽  
Petroleum Exploration

scholarly journals (U-Th)/He Thermochronology of the Ottawa Embayment, Eastern Canada: The Temperature-Time History of an Ancient, Intracratonic Rift Basin

2017 ◽  
Vol 125 (6) ◽  
pp. 659-680 ◽  
Author(s):  
R. A. Hardie ◽  
D. A. Schneider ◽  
J. I. Garver
Keyword(s):  
Time History ◽  
Rift Basin ◽  
Eastern Canada ◽  
History Of ◽  
Temperature Time

Run-on in Gasoline Engines

1968 ◽  
Vol 183 (1) ◽  
pp. 21-51 ◽  
Author(s):  
W. S. Affleck
Keyword(s):  
Combustion Chamber ◽  
Time History ◽  
Spontaneous Ignition ◽  
Research Octane Number ◽  
Gasoline Engines ◽  
Engine Cooling ◽  
History Of ◽  
Valve Overlap ◽  
Temperature Time ◽  
Small Valve

When the ignition of a car engine is switched off, the engine normally comes to rest within a few revolutions but, occasionally, it may continue to fire erratically for a few seconds or longer. This phenomenon is known as run-on and, for the majority of European engines, is the result of spontaneous ignition of the fuel-air mixture in the combustion chamber. Part 1 of this paper describes experiments in a single-cylinder research engine which have been made to establish the principles controlling run-on. In particular the effects of air/fuel ratio, the nature of the fuel and the pressure-temperature-time history of the fuel-air mixture in the combustion chamber have been studied, as it is known that these factors play an important part in spontaneous ignition in experiments in laboratory vessels. From these observations it has been possible to formulate a theoretical model of the run-on process which explains the salient features of the phenomenon. In particular, it shows how the gradual cooling of the engine limits the duration of run-on and also how the duration of run-on may be considered as a measure of the extent to which fuel or engine factors must be altered to eliminate run-on. Part 2 describes the application of these principles to car engines using normal commercial-type fuels. It is concluded that the following are important features in the control of run-on: the use of fuel of sufficiently high Research octane number, minimum opening of throttle at idle, sufficient time for cooling of the combustion chamber before the ignition is switched off, efficient engine cooling, and small valve overlap. Current devices for reducing exhaust emissions are likely, through their effects on these features, to increase the tendency of an engine run-on. Combustion chamber deposits, though, appear to have little influence.

2021 Offshore petroleum exploration acreage release

2021 ◽  
Vol 61 (2) ◽  
pp. 291
Author(s):  
Paul Trotman
Keyword(s):  
Manufacturing Industry ◽  
Oil And Gas ◽  
Domestic Demand ◽  
Liquefied Natural Gas ◽  
Petroleum Exploration ◽  
Demand Growth ◽  
Regulatory Frameworks ◽  
The Future ◽  
Policy Work ◽  
Offshore Petroleum

In 2020, the liquefied natural gas (LNG) trade saw a modest increase of 1%, which is in contrast to the strong growth of previous years. Recently, the global LNG trade has picked up following the easing of impacts from the pandemic and demand growth in Asia. An increase of 6% in the global LNG trade is expected in 2021 and 2022. Domestic demand for gas remains high, with gas being used both for residential supply and also as an essential feedstock for the manufacturing industry. With a projected domestic gas shortfall, the future exploration and development of oil and gas will play a key role in ensuring access to secure, reliable and affordable energy in the future as well as assisting economic recovery from the pandemic. The importance of remaining an attractive investment destination is essential. Our challenge is to not only strike the balance of being agile and adaptive to market disruptions but also provide robust policy and regulatory frameworks to underpin future investment in the sector. Against this backdrop, this paper provides details of the 2021 offshore petroleum exploration acreage release and information about the ongoing policy work of the department.

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