STRATIGRAPHIC CONCEPTS AND PETROLEUM POTENTIAL OF THE DENISON TROUGH, QUEENSLAND

1979 ◽  
Vol 19 (1) ◽  
pp. 43
Author(s):  
R. J. Paten ◽  
L. N. Brown ◽  
R. D. Groves
Keyword(s):  
Structural Control ◽  
High Potential ◽  
Source Rocks ◽  
East Central ◽  
Petroleum Potential ◽  
Area Source ◽  
Depositional Processes ◽  
Diagenetic Processes ◽  
Gas Fields ◽  
Active Exploration

The Denison Trough in east central Queensland contains up to 4600m of both marine and non-marine, Permian and Triassic rocks. The sequence comprises thick mature source rocks interlayered and interfingering with thick sandstone intervals. Good to excellent sandstone reservoirs occur, though their distribution and development is sporadic and controlled by both despositional and diagenetic processes. This is the main limitation to the potential of the area. Source rocks appear to be gas or gas/condensate prone, although liquids generation cannot be discounted.Exploration to date, comprising extensive seismic and the drilling of 39 exploration and 29 assessment wells, has led to the discovery of four small gas fields with combined reserves of approximately 850-1140m3 x 106. These reserves are insufficient to justify exploitation at this time. Apart from the fields, numerous gas shows and minor oil shows have been recorded throughout the Permian sequence, establishing beyond doubt that the trough is a hydrocarbon province.The trough is assessed as having a high potential for the discovery of additional gas reserves, with a possible 15-55m3 x 109 being present both in deep structural plays and in shallower, essentially stratigraphic, plays. Further successful exploration will require both good quality structural control, particularly at depth and a sound understanding of the depositional processes controlling the development of reservoir sands. Since active exploration effectively ceased in the area in 1970, a great deal of stratigraphic information has become available. This has led to a better understanding of the stratigraphy than was previously possible. In addition, advances in seismic technology over the last decade have made available much more reliable exploration tools, with respect to achieving good quality, deep structural control and to stratigraphic interpretation and reservoir trend prediction.The Denison Trough is considered to be one of the most prospective of Australia's onshore basins. It remains to be seen; however, if the application of present stratigraphic/depositional knowledge and new seismic technology will result in its potential being realised.

scholarly journals Petrographic characterization and petroleum potential of Mesozoic carbonate rock in Block 106, Northern Red river basin

2020 ◽  
Vol 2 (6) ◽  
pp. 146-164
Author(s):  
Bui Thi Luan ◽  
Lieu Kim Phuong
Keyword(s):  
River Basin ◽  
Carbonate Rock ◽  
Red River ◽  
Source Rocks ◽  
Petroleum Exploration ◽  
Exploration And Exploitation ◽  
Petroleum Potential ◽  
Depositional Processes ◽  
Red River Basin ◽  
Fractured Carbonate

Petroleum exploration and exploitation in Red River basin has been carried since the early 1960s of the 20th century, however until now its effectiveness has been still limited. Recently, the oil price is constantly changing so the efficiency of petroleum exploration and exploitation is particularly considered. Therefore, the assessment of petroleum potential and the direction of exploration are not only scientific research but also economic problem for developing countries in which there is Vietnam. The article considers that characteristic of carbonate petrography is along with intergration of interpreted seismic –stratigraphy and well logs, geochemistry analytic results of source rocks and related literatures as well. The purpose is to predict the petroleum potential of carbonate rock in block 106 and serve effectively in Petroleum exploration and exploitation in Red River basin Based on the analytic results, carbonate rock in the study area was impacted by tectonic activities such as mechanic compaction; dissolution forming fractures, stylolites; and post-depositional processes as recrystallization of minerals, creating vuggy, mouldic and intraparticle pores and dolomitization as well. Carbonate rock contains fossils as foraminifera, coral, algae, echinoderm with subordinate brachiopod, bryozoa. Most of them are mudstone, wackestone with mud-supported and packstone is made up of abundant fossils. Locally, carbonate rock was fractured and filled up by calcite and silic. Oil and gas traces have been discovered in Mesozoic carbonate rock, block 106, northern Red River basin. Fractured carbonate rock and weathered carbonate rock in the structures as A, C and E are oil fields. Oil migrates into traps that were early formed in fractured carbonate basement rock masses that were buried in pre-Kainozoi.

Timing of fluorite mineralization and exhumation events in the east Central Alborz Mountains, northern Iran: constraints from fluorite (U–Th)/He thermochronometry

2021 ◽  
pp. 1-17
Author(s):  
Behnam Shafiei Bafti ◽  
István Dunkl ◽  
Saeed Madanipour
Keyword(s):  
Thermal Relaxation ◽  
Geothermal Gradient ◽  
Source Rocks ◽  
Lower Amount ◽  
Mining District ◽  
Northern Iran ◽  
East Central ◽  
Central Alborz ◽  
Ore Mineralization ◽  
History Of

Abstract The recently developed fluorite (U–Th)/He thermochronology (FHe) technique was applied to date fluorite mineralization and elucidate the exhumation history of the Mazandaran Fluorspar Mining District (MFMD) located in the east Central Alborz Mountains, Iran. A total of 32 fluorite single-crystal samples from four Middle Triassic carbonate-hosted fluorite deposits were dated. The presented FHe ages range between c. 85 Ma (age of fluorite mineralization) and c. 20 Ma (erosional cooling during the exhumation of the Alborz Mountains). The Late Cretaceous FHe ages (i.e. 84.5 ± 3.6, 78.8 ± 4.4 and 72.3 ± 3.5 Ma) are interpreted as the age of mineralization and confirm an epigenetic origin for ore mineralization in the MFMD, likely a result of prolonged hydrothermal circulation of basinal brines through potential source rocks. Most FHe ages scatter around the Eocene Epoch (55.4 ± 3.9 to 33.1 ± 1.7 Ma), recording an important cooling event after heating by regional magmatism in an extensional tectonic regime. Cooling of the heated fluorites, as a result of thermal relaxation in response to geothermal gradient re-equilibration after the end of magmatism, or exhumation cooling during extensional tectonics characterized by lower amount of erosion are most probably the causes of the recorded Eocene FHe cooling ages. Oligocene–Miocene FHe ages (i.e. 27.6 ± 1.4 to 19.5 ± 1.1 Ma) are related to the accelerated uplift of the whole Alborz Mountains, possibly as a result of the initial collision between the Afro-Arabian and Eurasian plates further to the south.

The Yenisei-Khatanga Composite Tectono-Sedimentary Element, Northern Siberia

2021 ◽  
pp. M57-2021-15
Author(s):  
E. V. Deev ◽  
G. G. Shemin ◽  
V. A. Vernikovsky ◽  
O. I. Bostrikov ◽  
P. A. Glazyrin ◽  
...  
Keyword(s):  
Siberian Craton ◽  
Middle Triassic ◽  
Foreland Basin ◽  
Early Carboniferous ◽  
Source Rocks ◽  
Total Thickness ◽  
Petroleum Potential ◽  
Early Paleocene ◽  
Middle Carboniferous ◽  
Severnaya Zemlya

AbstractThe Yenisei-Khatanga Composite Tectono-Sedimentary Element (YKh CTSE) is located between the Siberian Craton and the Taimyr-Severnaya Zemlya fold-and-thrust belt. The total thickness of the Mesoproterozoic-Cenozoic sediments of YKh CTSE reaches 20 to 25 km. They are divided into four tectono-sedimentary elements (TSE): (i) Mesoproterozoic-early Carboniferous Siberian Craton continental margin, (ii) middle Carboniferous-Middle Triassic syn-orogenic Taimyr foreland basin, (iii) late Permian-Early Triassic syn-rift, and (iv) Triassic-Early Paleocene post-rift. The last one is the most important in terms of its petroleum potential and is the most drilled part of the CTSE. Its thickness accounts for half of the total thickness of YKh CTSE. The margins of the post-rift TSE and the inner system of inversion swells and adjacent troughs and depressions were shaped by three tectonic events: (i) middle Carboniferous-Middle Triassic Taimyr orogeny, (ii) Late Jurassic-Early Cretaceous Verkhoyansk orogeny, (iii) Late Cenozoic uplift. These processes led to more intense migration of hydrocarbons, the trap formation and their infill with hydrocarbons. Triassic, Jurassic, and Lower Cretaceous source rocks are mostly gas-prone, and among 20 discovered fields in Jurassic and Cretaceous plays, 17 are gas or mixed-type fields.

An overview of the Ionian zone source rocks and petroleum potential of NW Greece (Ioannina concession block)

First Break ◽  
2014 ◽  
Vol 32 (12) ◽  
Author(s):  
Henry David ◽  
Constantinos Tzimeas ◽  
Paschalia Kiomourtzi ◽  
Panagiotis Konstantopoulos ◽  
George Panagopoulos ◽  
...  
Keyword(s):  
Source Rocks ◽  
Petroleum Potential

scholarly journals Biomarkers and C and S Isotopes of the Permian to Triassic Solid Bitumen and Its Potential Source Rocks in NE Sichuan Basin

Geofluids ◽  
2017 ◽  
Vol 2017 ◽  
pp. 1-14 ◽  
Author(s):  
Chunfang Cai ◽  
Chenlu Xu ◽  
Wenxiang He ◽  
Chunming Zhang ◽  
Hongxia Li
Keyword(s):  
Source Rock ◽  
Vitrinite Reflectance ◽  
Lower Triassic ◽  
Source Rocks ◽  
Upper Permian ◽  
Solid Bitumen ◽  
Lower Silurian ◽  
High Maturity ◽  
Gas Fields ◽  
Extractable Organic Matter

The potential parent source rocks except from Upper Permian Dalong Formation (P3d) for Upper Permian and Lower Triassic solid bitumen show high maturity to overmaturity with equivalent vitrinite reflectance (ERo) from 1.7% to 3.1% but have extractable organic matter likely not contaminated by younger source rocks. P3d source rocks were deposited under euxinic environments as indicated by the pyrite δ34S values as light as -34.5‰ and distribution of aryl isoprenoids, which were also detected from the Lower Silurian (S1l) source rock and the solid bitumen in the gas fields in the west not in the east. All the solid bitumen not altered by thermochemical sulfate reduction (TSR) has δ13C and δ34S values similar to part of the P3l kerogens and within the S1l kerogens. Thus, the eastern solid bitumen may have been derived from the P3l kerogens, and the western solid bitumen was likely to have precracking oils from P3l kerogens mixed with the S1l or P3d kerogens. This case-study tentatively shows that δ13C and δ34S values along with biomarkers have the potential to be used for the purpose of solid bitumen and source rock correlation in a rapidly buried basin, although further work should be done to confirm it.

The discovery of a new sedimentary basin: offshore Raukumara, East Coast, North Island, New Zealand

2008 ◽  
Vol 48 (1) ◽  
pp. 53 ◽  
Author(s):  
Chris Uruski ◽  
Callum Kennedy ◽  
Rupert Sutherland ◽  
Vaughan Stagpoole ◽  
Stuart Henrys
Keyword(s):  
New Zealand ◽  
Oil And Gas ◽  
East Coast ◽  
Plate Boundary ◽  
Source Rocks ◽  
Fault System ◽  
Northern Coast ◽  
The South ◽  
Petroleum Potential ◽  
The North

The East Coast of North Island, New Zealand, is the site of subduction of the Pacific below the Australian plate, and, consequently, much of the basin is highly deformed. An exception is the Raukumara Sub-basin, which forms the northern end of the East Coast Basin and is relatively undeformed. It occupies a marine plain that extends to the north-northeast from the northern coast of the Raukumara Peninsula, reaching water depths of about 3,000 m, although much of the sub-basin lies within the 2,000 m isobath. The sub-basin is about 100 km across and has a roughly triangular plan, bounded by an east-west fault system in the south. It extends about 300 km to the northeast and is bounded to the east by the East Cape subduction ridge and to the west by the volcanic Kermadec Ridge. The northern seismic lines reveal a thickness of around 8 km increasing to 12–13 km in the south. Its stratigraphy consists of a fairly uniformly bedded basal section and an upper, more variable unit separated by a wedge of chaotically bedded material. In the absence of direct evidence from wells and samples, analogies are drawn with onshore geology, where older marine Cretaceous and Paleogene units are separated from a Neogene succession by an allochthonous series of thrust slices emplaced around the time of initiation of the modern plate boundary. The Raukumara Sub-basin is not easily classified. Its location is apparently that of a fore-arc basin along an ocean-to-ocean collision zone, although its sedimentary fill must have been derived chiefly from erosion of the New Zealand land mass. Its relative lack of deformation introduces questions about basin formation and petroleum potential. Although no commercial discoveries have been made in the East Coast Basin, known source rocks are of marine origin and are commonly oil prone, so there is good potential for oil as well as gas in the basin. New seismic data confirm the extent of the sub-basin and its considerable sedimentary thickness. The presence of potential trapping structures and direct hydrocarbon indicators suggest that the Raukumara Sub-basin may contain large volumes of oil and gas.

HYDROCARBON HABITAT OF THE SURAT/BOWEN BASIN

1982 ◽  
Vol 22 (1) ◽  
pp. 213 ◽  
Author(s):  
B. M. Thomas ◽  
D. G. Osborne ◽  
A. J. Wright
Keyword(s):  
Oil And Gas ◽  
Lower Jurassic ◽  
Source Rocks ◽  
Lateral Migration ◽  
Early Maturity ◽  
Oil And Gas Fields ◽  
Basement Rocks ◽  
Origin Of Oil ◽  
Gas Fields ◽  
Geochemical Studies

Ever since the early discoveries at Cabawin (1960) and Moonie (1961), the origin of oil and gas in the Surat/Bowen Basin has been a subject of speculation. Hydrocarbons have been found in reservoirs ranging in age from Permian to Early Jurassic; even fractured pre-Permian 'basement' rocks have occasionally recorded shows.Recent geochemical studies have identified rich source rocks within the Jurassic, Triassic and Permian sequences. The Middle Jurassic Walloon Coal Measures are thermally immature throughout the Surat Basin and are unlikely to have generated significant amounts of hydrocarbons. Lower Jurassic Evergreen Formation source rocks have reached 'nominal early maturity' (VR = 0.6) in parts of the basin. The Middle Triassic Moolayember Formation lies within the oil generation zone in the northern Taroom Trough. However, no oil has yet been confidently correlated with either a Jurassic or a Triassic source. On geochemical and geological grounds it is likely that most, if not all, of the hydrocarbons discovered to date were generated from Permian source rocks.The probability of finding gas as well as oil in Permian, Triassic or Jurassic reservoirs increases from south to north, in accord with organic maturity trends in the Permian of the Taroom Trough. On the narrow thrust-bounded eastern flank, vertical migration has occurred, resulting in oilfields at Moonie and Bennett. In contrast, extensive lateral migration of hydrocarbons across the gentle western flank of the basin is indicated by numerous small oil and gas fields on the Roma Shelf and Wunger Ridge.

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