Geology and prospectivity of the Capel and Faust basins in the deepwater Tasman Sea region

2011 ◽  
Vol 51 (2) ◽  
pp. 702
Author(s):  
Takehiko Hashimoto ◽  
Karen Higgins ◽  
Nadege Rollet ◽  
Vaughan Stagpoole ◽  
Peter Petkovic ◽  
...  
Keyword(s):  
Upper Cretaceous ◽  
Source Rocks ◽  
Gas Generation ◽  
Potential Source ◽  
Tasman Sea ◽  
Sample Data ◽  
Frontier Region ◽  
Reduce Risk ◽  
Sedimentary Succession ◽  
The Government

Geoscience Australia recently completed a petroleum prospectivity assessment of the Capel and Faust basins as part of the Australian government's energy security program. This pre-competitive study was carried out in collaboration with GNS Science and the government of New Caledonian, and was based on seismic, potential field, multibeam bathymetry and sample data acquired during marine surveys in 2006–7. The Capel and Faust basins are located in the Tasman Sea region, which contains a number of deepwater basins. There is little information about their geology. The Geoscience Australia study confirmed the existence of large compartmentalised depocentres containing sediments up to 6 km thick. The basins formed during two Cretaceous extensional episodes related to the final breakup of eastern Gondwana. Syn-rift deposition appears to have been initially dominated by volcanics and volcaniclastics, then dominated by non-marine to shallow marine clastics. The post-rift succession comprises upward-fining clastic to calcareous bathyal sediments. A pre-rift (?Mesozoic) sedimentary succession appears to underlie some depocentres. Mesozoic successions in nearby eastern Australian and New Zealand basins suggest that fluvio-deltaic potential source rocks (Triassic/Jurassic to Upper Cretaceous coals) may occur in the pre-rift and syn-rift successions of the Capel and Faust basins. Multi-1D basin modelling suggests that the deeper depocentres are presently within the oil or gas generation window and that expulsion occurred from the Early Cretaceous. Fluvio-deltaic, shoreline and turbiditic sandstones may provide potential reservoirs. Likely play types include large anticlines, fault blocks, unconformities, and stratigraphic pinchouts. The results will guide future exploration and reduce risk in this vast frontier region.

EXPLORATION POTENTIAL OF THE TIMOR GAP ZONE OF CO-OPERATION

1990 ◽  
Vol 30 (1) ◽  
pp. 68 ◽  
Author(s):  
Peter Botten ◽  
Keiran Wulff
Keyword(s):  
Continental Shelf ◽  
Upper Cretaceous ◽  
Oil And Gas ◽  
Source Rocks ◽  
Small Data ◽  
Insufficient Information ◽  
Large Area ◽  
Potential Source ◽  
Timor Sea ◽  
Evaluation Of Data

The area covered by the Zone of Co-operation (ZOC) in the eastern Timor Sea represents the last large area of sparsely explored continental shelf around Australia that has obvious potential for significant hydrocarbon accumulations.Extravagant claims about the assumed exploration potential of the area have been widely published in Australia and Indonesia. The low level of exploration within the Zone does not allow confident prediction of potential at this time. Only five wells and less than 20 000 km of seismic are present in the ZOC. A similar level of exploration had been reached in the Ashmore-Cartier area in the western Timor Sea by 1972. With such a small data base, extrapolation of conclusions drawn from exploration of adjacent areas is fundamental to the present evaluation.Many technical comparisons can be made between the ZOC and the heavily explored Ashmore-Cartier area. Evaluation of data within the ZOC and extrapolation of important information from other parts of the Timor Sea indicates that all the prerequisites for hydrocarbon accumulations exist within the area.Jurassic reservoirs sealed by the Cretaceous Bathurst Island Formation provide the primary reservoir objectives in all areas of the ZOC away from the Malita Graben. Oil recovered in wells situated on the Londonderry High has been correlated with mature source rocks of the Jurassic Plover Formation in the Sahul Syncline. This depocentre is concluded to have the capacity of generating both oil and gas for potential accumulations in the southern and western part of the ZOC. The capacity of the Malita Graben to source major volumes of hydrocarbons from potential source rocks of the Flamingo Group is still to be established. Insufficient information is available to reliably predict the distribution of oil and gas in the ZOC.Play types similar to those seen in the Ashmore-Cartier area are present in the ZOC. Fault-controlled horst plays, typified by the Jabiru Field, are prevalent on the Sahul Platform. Upper Cretaceous sandstone plays dominate the southern part of the ZOC where reservoir objectives in the Jurassic Plover Formation and Flamingo Group are considered to be too deep for economic exploration.Application of some of the exploration lessons learnt in the western Timor Sea is essential to future activities in the ZOC in order to minimise possible discovery costs.

Upper Cretaceous palaeoenvironments and benthonic foraminiferal assemblages of potential source rocks from the western African margin, Central Atlantic

1999 ◽  
Vol 153 (1) ◽  
pp. 195-222 ◽  
Author(s):  
Ann Holbourn ◽  
Wolfgang Kuhnt ◽  
Abderrazzak El Albani ◽  
Thomas Pletsch ◽  
Florian Luderer ◽  
...  
Keyword(s):  
Upper Cretaceous ◽  
Source Rocks ◽  
Potential Source ◽  
Central Atlantic

scholarly journals Evaluation of the quality, thermal maturity and distribution of potential source rocks in the Danish part of the Norwegian–Danish Basin

2008 ◽  
Vol 16 ◽  
pp. 1-66 ◽  
Author(s):  
Henrik I. Petersen ◽  
Lars H. Nielsen ◽  
Jørgen A. Bojesen-Koefoed ◽  
Anders Mathiesen ◽  
Lars Kristensen ◽  
...  
Keyword(s):  
Source Rock ◽  
Early Cretaceous ◽  
Middle Jurassic ◽  
Upper Cretaceous ◽  
Vitrinite Reflectance ◽  
Lower Jurassic ◽  
Source Rocks ◽  
Thermal Maturity ◽  
Potential Source ◽  
Petroleum Generation

The quality, thermal maturity and distribution of potential source rocks within the Palaeozoic–Mesozoic succession of the Danish part of the Norwegian-Danish Basin have been evaluated on the basis of screening data from over 4000 samples from the pre-Upper Cretaceous succession in 33 wells. The Lower Palaeozoic in the basin is overmature and the Upper Cretaceous – Cenozoic strata have no petroleum generation potential, but the Toarcian marine shales of the Lower Jurassic Fjerritslev Formation (F-III, F-IV members) and the uppermost Jurassic – lowermost Cretaceous shales of the Frederikshavn Formation may qualify as potential source rocks in parts of the basin. Neither of these potential source rocks has a basinwide distribution; the present occurrence of the Lower Jurassic shales was primarily determined by regional early Middle Jurassic uplift and erosion. The generation potential of these source rocks is highly variable. The F-III and F-IV members show significant lateral changes in generation capacity, the best-developed source rocks occurring in the basin centre. The combined F-III and F-IV members in the Haldager-1, Kvols-1 and Rønde-1 wells contain 'net source-rock' thicknesses (cumulative thickness of intervals with Hydrogen Index (HI)> 200 mg HC/g TOC) of 40 m, 83 m, and 92 m, respectively, displaying average HI values of 294, 369 and 404 mg HC/g TOC. The Mors-1 well contains 123 m of 'net source rock' with an average HI of 221 mg HC/g TOC. Parts of the Frederikshavn Formation possess a petroleum generation potential in the Hyllebjerg-1, Skagen-2, Voldum-1 and Terne-1 wells, the latter well containing a c. 160 m thick highly oil-prone interval with an average HI of 478 mg HC/g TOC and maximum HI values> 500 mg HC/g TOC.The source-rock evaluation suggests that a Mesozoic petroleum system is the most likely in the study area. Two primary plays are possible: (1) the Upper Triassic – lowermost Jurassic Gassum play, and (2) the Middle Jurassic Haldager Sand play. Potential trap structures are widely distributed in the basin, most commonly associated with the flanks of salt diapirs. The plays rely on charge from the Lower Jurassic (Toarcian) or uppermost Jurassic – lowermost Cretaceous shales. Both plays have been tested with negative results, however, and failure is typically attributed to insufficient maturation (burial depth) of the source rocks. This maturation question has been investigated by analysis of vitrinite reflectance data from the study area, corrected for post-Early Cretaceous uplift. A likely depth to the top of the oil window (vitrinite reflectance = 0.6%Ro) is c. 3050–3100 m based on regional coalification curves. The Frederikshavn Formation had not been buried to this depth prior to post-Early Cretaceous exhumation, and the potential source rocks of the formation are thermally immature in terms of hydrocarbon generation. The potential source rocks of the Fjerritslev Formation are generally immature to very early mature. Mature source rocks in the Danish part of the Norwegian–Danish Basin are thus dependent on local, deeper burial to reach the required thermal maturity for oil generation. Such potential kitchen areas with mature Fjerritslev Formation source rocks may occur in the central part of the study area (central–northern Jylland), and a few places offshore. These inferred petroleum kitchens are areally restricted, mainly associated with salt structures and local grabens (such as the Fjerritslev Trough and the Himmerland Graben).

Burial History Reconstruction of the Appalachian Basin in Kentucky, West Virginia, Pennsylvania, and New York, Using 1D Petroleum System Models

2019 ◽  
Vol 56 (4) ◽  
pp. 365-396
Author(s):  
Debra Higley ◽  
Catherine Enomoto
Keyword(s):  
New York ◽  
Vitrinite Reflectance ◽  
Structural Complexity ◽  
Appalachian Basin ◽  
Source Rocks ◽  
Burial History ◽  
Gas Generation ◽  
Deep Basin ◽  
Utica Shale ◽  
Wet Gas

Nine 1D burial history models were built across the Appalachian basin to reconstruct the burial, erosional, and thermal maturation histories of contained petroleum source rocks. Models were calibrated to measured downhole temperatures, and to vitrinite reflectance (% Ro) data for Devonian through Pennsylvanian source rocks. The highest levels of thermal maturity in petroleum source rocks are within and proximal to the Rome trough in the deep basin, which are also within the confluence of increased structural complexity and associated faulting, overpressured Devonian shales, and thick intervals of salt in the underlying Silurian Salina Group. Models incorporate minor erosion from 260 to 140 million years ago (Ma) that allows for extended burial and heating of underlying strata. Two modeled times of increased erosion, from 140 to 90 Ma and 23 to 5.3 Ma, are followed by lesser erosion from 5.3 Ma to Present. Absent strata are mainly Permian shales and sandstone; thickness of these removed layers increased from about 6200 ft (1890 m) west of the Rome trough to as much as 9650 ft (2940 m) within the trough. The onset of oil generation based on 0.6% Ro ranges from 387 to 306 Ma for the Utica Shale, and 359 to 282 Ma for Middle Devonian to basal Mississippian shales. The ~1.2% Ro onset of wet gas generation ranges from 360 to 281 Ma in the Utica Shale, and 298 to 150 Ma for Devonian to lowermost Mississippian shales.

A possible new hydrocarbon play, offshore central West Greenland

1998 ◽  
pp. 28-30
Author(s):  
Nina Skaarup ◽  
James A. Chalmers
Keyword(s):  
Seismic Data ◽  
Mineral Resources ◽  
Source Rocks ◽  
Bright Spot ◽  
Offshore Area ◽  
West Greenland ◽  
The Government ◽  
Structural Closure ◽  
Multichannel Seismic Data ◽  
Seismic Lines

NOTE: This article was published in a former series of GEUS Bulletin. Please use the original series name when citing this article, for example: Skaarup, N., & Chalmers, J. A. (1998). A possible new hydrocarbon play, offshore central West Greenland. Geology of Greenland Survey Bulletin, 180, 28-30. https://doi.org/10.34194/ggub.v180.5082 _______________ The discovery of extensive seeps of crude oil onshore central West Greenland (Christiansen et al. 1992, 1994, 1995, 1996, 1997, 1998, this volume; Christiansen 1993) means that the central West Greenland area is now prospective for hydrocarbons in its own right. Analysis of the oils (Bojesen-Koefoed et al. in press) shows that their source rocks are probably nearby and, because the oils are found within the Lower Tertiary basalts, the source rocks must be below the basalts. It is therefore possible that in the offshore area oil could have migrated through the basalts and be trapped in overlying sediments. In the offshore area to the west of Disko and Nuussuaq (Fig. 1), Whittaker (1995, 1996) interpreted a few multichannel seismic lines acquired in 1990, together with some seismic data acquired by industry in the 1970s. He described a number of large rotated fault-blocks containing structural closures at top basalt level that could indicate leads capable of trapping hydrocarbons. In order to investigate Whittaker’s (1995, 1996) interpretation, in 1995 the Geological Survey of Greenland acquired 1960 km new multichannel seismic data (Fig. 1) using funds provided by the Government of Greenland, Minerals Office (now Bureau of Minerals and Petroleum) and the Danish State through the Mineral Resources Administration for Greenland. The data were acquired using the Danish Naval vessel Thetis which had been adapted to accommodate seismic equipment. The data acquired in 1995 have been integrated with the older data and an interpretation has been carried out of the structure of the top basalt reflection. This work shows a fault pattern in general agreement with that of Whittaker (1995, 1996), although there are differences in detail. In particular the largest structural closure reported by Whittaker (1995) has not been confirmed. Furthermore, one of Whittaker’s (1995) smaller leads seems to be larger than he had interpreted and may be associated with a DHI (direct hydrocarbon indicator) in the form of a ‘bright spot’.

Study on the Forming Conditions of Shale Gas in Coal Measure of Wuli Area, Qinghai Province, China

2013 ◽  
Vol 295-298 ◽  
pp. 2770-2773 ◽  
Author(s):  
Dai Yong Cao ◽  
Jing Li ◽  
Ying Chun Wei ◽  
Xiao Yu Zhang ◽  
Chong Jing Wang
Keyword(s):  
Shale Gas ◽  
Thermal Evolution ◽  
Organic Matter Content ◽  
Gas Production ◽  
Matter Content ◽  
Source Rocks ◽  
Coal Measure ◽  
Gas Generation ◽  
Qinghai Province ◽  
Coal Measures

Besides coal seam, the source rocks including dark mudstone, carbon mudstone and so on account for a large proportion in the coal measures. Based on the complex geothermal evolution history, the majority of coal measure organic matters with the peak of gas generation have a good potential of gas. Therefore, shale gas in coal measure is an important part of the shale gas resources. There are good conditions including the thickness of coal measures, high proportion of shale rocks, rich in organic matter content, high degree of thermal evolution, high content of brittle mineral and good conditions of the porosity and permeability for the generation of shale gas in Wuli area, the south of Qinghai province. Also the direct evidence of the gas production has been obtained from the borehole. The evaluation of shale gas in coal measure resources could broaden the understanding of the shale gas resources and promote the comprehensive development of the coal resources.

scholarly journals Changes in the Portfolio Management and Construction under the Pandemic Era

2021 ◽  
Vol 275 ◽  
pp. 01005
Author(s):  
Ruipeng Tan
Keyword(s):  
Monte Carlo Simulation ◽  
Monte Carlo ◽  
Stock Returns ◽  
Financial Market ◽  
Portfolio Management ◽  
Portfolio Construction ◽  
Sample Data ◽  
Before And After ◽  
Reduce Risk ◽  
The Impact

This paper focuses on comparing portfolio management and construction before and after the coronavirus. First, this paper presents the importance of building up portfolios for investors to diversify their risks. Theories on portfolio management are discussed in this section to show how they have been developed to help on investing and reduce risk. Then, the paper moves on to show the impact of the pandemic on the financial market and portfolio management. Sample data on tech stock returns are collected to perform a Monte Carlo simulation on portfolio construction to find out the efficient portfolio before and after the COVID-19 outbreak. The efficient portfolio is build based on the Markowitz theory to find the combination. Comparisons between these portfolio constructions are made to find out the changes in portfolio management and construction under the pandemic era. In conclusion, this paper presents how pandemic has changed and impacted the investments and lists recommendations on future portfolio management and construction.

scholarly journals The Cambrian Henson Gletscher Formation: a mature to postmature hydrocarbon source rock sequence from North Greenland

1987 ◽  
Vol 133 ◽  
pp. 141-157
Author(s):  
F.G Christiansen ◽  
H Nøhr-Hansen ◽  
O Nykjær
Keyword(s):  
Source Rock ◽  
Source Rocks ◽  
Hydrocarbon Generation ◽  
Hydrocarbon Source Rock ◽  
Reservoir Rocks ◽  
Potential Source ◽  
Potential Reservoir ◽  
Field Season ◽  
North Greenland

During the 1985 field season the Cambrian Henson Gletscher Formation in central North Greenland was studied in detail with the aim of evaluating its potential as a hydrocarbon source rock. The formation contains organic rich shale and carbonate mudstone which are considered to be potential source rocks. These are sedimentologically coupled with a sequence of sandstones and coarse carbonates which might be potential reservoir rocks or migration conduits. Most of the rocks exposed on the surface are, however, thermally mature to postrnature with respect to hydrocarbon generation, leaving only few chances of finding trapped oil in the subsurface of the area studied in detail.

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