TECTONICS OF THE JACKSON-NACCOWLAH AREA, COOPER-EROMANGA BASINS, SOUTHWEST QUEENSLAND, AND THEIR IMPLICATIONS FOR HYDROCARBON ACCUMULATION

1985 ◽  
Vol 25 (1) ◽  
pp. 85
Author(s):  
A.W. Nelson
Keyword(s):  
Hydrocarbon Exploration ◽  
Source Rocks ◽  
Hydrocarbon Generation ◽  
Oil Accumulation ◽  
Basement Faults ◽  
Model Study ◽  
Fault Bend ◽  
Exploration Drilling ◽  
Wrench Fault ◽  
Occurrence Patterns

The Naccowlah-Jackson Trend in the Cooper-Eromanga Basins, southwest Queensland, has been the scene of a high hydrocarbon exploration drilling success ratio during the 1980s. The structural trend is mainly the result of sinistral convergent wrenching, which has given rise to a series of major reverse faults and two distinct series of relatively minor parallel and orthogonal basement faults. A parallel is drawn with fault patterns shown on a clay model study of a 15° convergent wrench fault. Productive structures result from intermittent growth on the fault trends since Early Permian, although original wrenching may have been pre-Permian. A releasing (divergent) fault bend is identified as an area of accumulation of a thick sequence of potential Permian source rock. Although this accumulation is well placed to have sourced the largest known oil accumulation on the trend, other drilling results tend to downgrade the potential of the local Permian sequence as a source.Structural growth due to wrenching has been responsible for a favourable integration of the components necessary for hydrocarbon generation and accumulation, but also appears to be responsible for crestal faulting which in several cases is interpreted to have led to the escape of hydrocarbons.Two basic oil types (Hutton type and Murta type) are known. The occurrence patterns of these are consistent with the Hutton type being derived from Jurassic source rocks, mature in the Nappamerri Trough, and the Murta type being sourced intra-formationally from source rocks which are marginally mature over most of the study area.

HYDROCARBON PROSPECTIVITY OF THE TORQUAY SUB-BASIN, OFFSHORE VICTORIA

1994 ◽  
Vol 34 (1) ◽  
pp. 479 ◽  
Author(s):  
Mark A. Trupp ◽  
Keith W. Spence ◽  
Michael J. Gidding
Keyword(s):  
Lower Cretaceous ◽  
Hydrocarbon Exploration ◽  
Source Rocks ◽  
Structural Deformation ◽  
Hydrocarbon Generation ◽  
Fault Block ◽  
Complex Fault ◽  
Wild Dog ◽  
Reservoir Potential ◽  
Gippsland Basin

The Torquay Sub-basin lies to the south of Port Phillip Bay in Victoria. It has two main tectonic elements; a Basin Deep area which is flanked to the southeast by the shallower Snail Terrace. It is bounded by the Otway Ranges to the northwest and shallow basement elsewhere. The stratigraphy of the area reflects the influence of two overlapping basins. The Lower Cretaceous section is equivalent to the Otway Group of the Otway Basin, whilst the Upper Cretaceous and Tertiary section is comparable with the Bass Basin stratigraphy.The Torquay Sub-basin apparently has all of the essential ingredients needed for successful hydrocarbon exploration. It has good reservoir-seal pairs, moderate structural deformation and probable source rocks in a deep kitchen. Four play types are recognised:Large Miocene age anticlines, similar to those in the Gippsland Basin, with an Eocene sandstone reservoir objective;The same reservoir in localised Oligocene anticlines associated with fault inversion;Possible Lower Cretaceous Eumeralla Formation sandstones in tilted fault blocks and faulted anticlines; andLower Cretaceous Crayfish Sub-group sandstones also in tilted fault block traps.Maturity modelling suggests that the Miocene anticlines post-date hydrocarbon generation. Poor reservoir potential and complex fault trap geometries downgrade the two Lower Cretaceous plays.The Oligocene play was tested by Wild Dog-1 which penetrated excellent Eocene age reservoir sands beneath a plastic shale seal, however, the well failed to encounter any hydrocarbons. Post-mortem analysis indicates the well tested a valid trap. The failure of the well is attributed to a lack of charge. Remaining exploration potential is limited to the deeper plays which have much greater risks associated with each play element.

scholarly journals Hydrocarbon generation and expulsion of Middle Jurassic lacustrine source rocks in the Turpan–Hami Basin, NW China: Implications for tight oil accumulation

2020 ◽  
pp. 014459872095629
Author(s):  
Yue Feng ◽  
Zhilong Huang ◽  
Tianjun Li ◽  
Enze Wang ◽  
Hua Zhang ◽  
...  
Keyword(s):  
Middle Jurassic ◽  
Potential Method ◽  
Source Rocks ◽  
Western China ◽  
Tight Oil ◽  
Hydrocarbon Generation ◽  
Pore Throat ◽  
Throat Radius ◽  
Oil Accumulation ◽  
Average Pore

In recent years, new oil reservoirs have been discovered in the middle Jurassic tight mixed rocks of the Turpan–Hami Basin. However, the generation potential of the J2q2 source rocks remains poorly understood. Petrographic, petrological, and geochemical analyses were carried out to assess the quality of the J2q2 source and reservoir rocks. The hydrocarbon generation potential method was utilized to evaluate the hydrocarbon generation and expulsion potentials. The results indicated that the rocks can be classified as high-quality source rocks with a relative lower degree of maturity. The hydrocarbon bearing zones are classified as tight reservoirs (average porosity of 5.90% and permeability of 0.18 mD) with an average pore throat radius >150 nm, which is higher than the cut-off pore-throat radius. The source rocks start to expel hydrocarbons when Ro% is 0.56%. Bulk hydrocarbon generation and expulsion intensities in the center of the study area were calculated with the values of 900 × 104 t/km2 and 400 × 104 t/km2, while the weights of these hydrocarbons were 48.8 × 108 t and 27.3 × 108 t, respectively. The tight oil reservoir-forming conditions are superior, and the hydrocarbon generation and expulsion intensities are more remarkable in controlling the tight oil distribution. This study provides an important example for the Jurassic source rocks in Western China, and indicates that middle Jurassic lacustrine source rocks deserve attention in future exploration.

scholarly journals Thermal and maturation history for Carboniferous source rocks in the Junggar Basin, Northwest China: implications for hydrocarbon exploration

2020 ◽  
Vol 17 (1) ◽  
pp. 36-50 ◽  
Author(s):  
Di Hu ◽  
Song Rao ◽  
Zhu-Ting Wang ◽  
Sheng-Biao Hu
Keyword(s):  
Heat Flow ◽  
Thermal History ◽  
Thermal State ◽  
Junggar Basin ◽  
Hydrocarbon Exploration ◽  
Source Rocks ◽  
Hydrocarbon Generation ◽  
Early Maturation ◽  
Hydrocarbon Maturation ◽  
History Of

AbstractThe reconstruction of thermal history is an important component of basin evolution and hydrocarbon exploration. Based on vitrinite reflectance data, we integrate the paleo-temperature gradient and paleo-heat flow methods to reconstruct the thermal history of Junggar Basin. Compared with present thermal state, the Junggar Basin experienced much a higher heat flow of ca. 80–120 mW/m2 during the Carboniferous. This feature can be attributed to large-scale volcanic events and related thermal effects. The hydrocarbon maturation history of Carboniferous source rocks indicates that the temperature rapidly reached the threshold of hydrocarbon generation during the Late Carboniferous and has never achieved such a high level since then. This characteristic resulted in the early maturation of hydrocarbons in Carboniferous source rocks. Meanwhile, the results reveal that hydrocarbon maturities are different among various tectonic units in Junggar Basin. The kerogen either rapidly broke through the dry gas period so that cracking of gas occurred or remained in the oil maturation window forming oil reservoirs, which depended on the tectonic background and depositional environment. In this study, we present the thermal and hydrocarbon maturation history since the Carboniferous, which has important implications for further hydrocarbon exploration in Junggar Basin.

scholarly journals Quality, hydrocarbon generation, and expulsion of the Eocene Enping Formation source rocks in the Wenchang Depression, western Pearl River Mouth Basin, South China Sea

2020 ◽  
Vol 38 (6) ◽  
pp. 2169-2198
Author(s):  
Jinheng Li ◽  
Dongxia Chen ◽  
Lu Chang ◽  
Guangjie Xie ◽  
Xuebin Shi ◽  
...  
Keyword(s):  
South China Sea ◽  
South China ◽  
Oil And Gas ◽  
River Mouth ◽  
Hydrocarbon Exploration ◽  
Source Rocks ◽  
Pearl River ◽  
Pearl River Mouth Basin ◽  
Hydrocarbon Generation ◽  
China Sea

Recently, increasing numbers of oil and gas reservoirs have been discovered in the Wenchang Depression, western Pearl River Mouth Basin, South China Sea, revealing prospects for hydrocarbon exploration. The Enping Formation (E3e) is a key target layer for the development of source rocks. However, previous work has only focused on lacustrine swamp source rocks of E3e in the Wenchang A Sag, without a systematic study of shallow lacustrine source rocks. In this study, the quality of E3e shallow lacustrine source rocks is reevaluated, and the hydrocarbon generation and expulsion characteristics are analyzed using relevant geological data and constructing a conceptual model. The results show that the E3e2 source rocks have greater thickness (50–600 m) and similar organic matter abundance (0.5–2.5%) compared with the E3e1 source rocks (50–500 m and 0.5–2.5%). On the whole, the E3e source rocks were deposited in the continental environment and are dominated by Type II and Type III kerogen. Meanwhile, the E3e source rocks of the Wenchang A Sag are in the stage of mature to over mature, while those of the Wenchang B Sag are in the stage of low mature. Vertically, the hydrocarbon generation potential of the E3e2 source rocks is greater than E3e1. Also, the cumulative hydrocarbon production of steep slope in the Wenchang A Sag is larger than that in the Wenchang B Sag. In addition, the corresponding vitrinite reflectances of hydrocarbon expulsion threshold and peak are 0.72 and 0.96%, respectively. Horizontally, four hydrocarbon generation and expulsion centers were mainly concentrated in different subsags of the Wenchang A and B Sags for E3e. The maximum values of hydrocarbon generation and expulsion intensity for E3e1 are 1500 × 104 t/km2 and 1000 × 104 t/km2, respectively, while those for E3e2 are 1800 × 104 t/km2 and 1200 × 104 t/km2, respectively, with the expulsion efficiency of 75%.

Oil to Source Rock Correlation Using Biomarker Data Through Pattern Matching and Fingerprinting Analysis in “Kitkat” Field, Jabung Block, South Sumatra Basin

2020 ◽  
Author(s):  
S., R. Muthasyabiha
Keyword(s):  
Pattern Matching ◽  
Source Rock ◽  
Vitrinite Reflectance ◽  
Hydrocarbon Exploration ◽  
Source Rocks ◽  
Maturity Level ◽  
Fingerprinting Analysis ◽  
Kerogen Type ◽  
Oil Characteristics ◽  
Biomarker Data

Geochemical analysis is necessary to enable the optimization of hydrocarbon exploration. In this research, it is used to determine the oil characteristics and the type of source rock candidates that produces hydrocarbon in the “KITKAT” Field and also to understand the quality, quantity and maturity of proven source rocks. The evaluation of source rock was obtained from Rock-Eval Pyrolysis (REP) to determine the hydrocarbon type and analysis of the value of Total Organic Carbon (TOC) was performed to know the quantity of its organic content. Analysis of Tmax value and Vitrinite Reflectance (Ro) was also performed to know the maturity level of the source rock samples. Then the oil characteristics such as the depositional environment of source rock candidate and where the oil sample develops were obtained from pattern matching and fingerprinting analysis of Biomarker data GC/GCMS. Moreover, these data are used to know the correlation of oil to source rock. The result of source rock evaluation shows that the Talangakar Formation (TAF) has all these parameters as a source rock. Organic material from Upper Talangakar Formation (UTAF) comes from kerogen type II/III that is capable of producing oil and gas (Espitalie, 1985) and Lower Talangakar Formation (LTAF) comes from kerogen type III that is capable of producing gas. All intervals of TAF have a quantity value from very good–excellent considerable from the amount of TOC > 1% (Peters and Cassa, 1994). Source rock maturity level (Ro > 0.6) in UTAF is mature–late mature and LTAF is late mature–over mature (Peters and Cassa, 1994). Source rock from UTAF has deposited in the transition environment, and source rock from LTAF has deposited in the terrestrial environment. The correlation of oil to source rock shows that oil sample is positively correlated with the UTAF.

Kinetic study of the hydrocarbon generation from marine carbonate source rocks characterization of products of gas and liquid hydrocarbon

2006 ◽  
Vol 51 (23) ◽  
pp. 2885-2891 ◽  
Author(s):  
Xinhua Geng ◽  
Ansong Geng ◽  
Yongqiang Xiong ◽  
Jinzhong Liu ◽  
Haizu Zhang ◽  
...  
Keyword(s):  
Kinetic Study ◽  
Liquid Hydrocarbon ◽  
Source Rocks ◽  
Hydrocarbon Generation ◽  
Marine Carbonate ◽  
Carbonate Source

scholarly journals HYDROCARBON GENERATION AND MIGRATION FROM BARREMIAN – APTIAN SOURCE ROCKS, NORTHERN ORANGE BASIN, OFFSHORE WESTERN SOUTH AFRICA: A 3D NUMERICAL MODELLING STUDY

2021 ◽  
Vol 44 (2) ◽  
pp. 187-208
Author(s):  
C. A. Samakinde ◽  
J. M. van Bever Donker ◽  
R. Durrheim ◽  
M. Manzi
Keyword(s):  
South Africa ◽  
Numerical Modelling ◽  
Source Rocks ◽  
Hydrocarbon Generation ◽  
3D Numerical Modelling ◽  
And Migration ◽  
Modelling Study
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