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Articles de revues sur le sujet « Petroleum Source Rocks »

Auteur : Grafiati

Publié le 4 juin 2021

Mis à jour le 9 février 2022

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1

Tyson, R. V. "Petroleum source rocks." Organic Geochemistry 23, no. 10 (1995): 995. http://dx.doi.org/10.1016/0146-6380(95)90072-1.

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Piggott, Neil. "Petroleum source rocks." Marine and Petroleum Geology 13, no. 5 (1996): 593. http://dx.doi.org/10.1016/0264-8172(96)88332-2.

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Cohen, Andrew S., A. J. Fleet, K. Kelts, and M. Talbot. "Lacustrine Petroleum Source Rocks." PALAIOS 4, no. 3 (1989): 294. http://dx.doi.org/10.2307/3514778.

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Hunt, John M. "Marine petroleum source rocks." Geochimica et Cosmochimica Acta 53, no. 5 (1989): 1156. http://dx.doi.org/10.1016/0016-7037(89)90224-x.

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Robbins, Eleanora I. "Lacustrine petroleum source rocks." Geochimica et Cosmochimica Acta 53, no. 7 (1989): 1711. http://dx.doi.org/10.1016/0016-7037(89)90258-5.

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Frostick, L. E. "Lacustrine petroleum source rocks." Marine and Petroleum Geology 7, no. 2 (1990): 199–200. http://dx.doi.org/10.1016/0264-8172(90)90045-i.

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Hall, Lisa, Tehani Palu, Chris Boreham, et al. "Cooper Basin source rock atlas." APPEA Journal 56, no. 2 (2016): 594. http://dx.doi.org/10.1071/aj15100.

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The Australian Petroleum Source Rocks Mapping project is a new study to improve understanding of the petroleum resource potential of Australia’s sedimentary basins. The Permian source rocks of the Cooper Basin, Australia’s premier onshore hydrocarbon-producing province, are the first to be assessed for this project. Quantifying the spatial distribution and petroleum generation potential of these source rocks is critical for understanding both the conventional and unconventional hydrocarbon prospectivity of the basin. Source rock occurrence, thickness, quality and maturity are mapped across the

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JIANG, DE-XIN, YONG-DONG WANG, ELEANORA I. ROBBINS, JIANG WEI, and NING TIAN. "Mesozoic non-marine petroleum source rocks determined by palynomorphs in the Tarim Basin, Xinjiang, northwestern China." Geological Magazine 145, no. 6 (2008): 868–85. http://dx.doi.org/10.1017/s0016756808005384.

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AbstractThe Tarim Basin in Northwest China hosts petroleum reservoirs of Cambrian, Ordovician, Carboniferous, Triassic, Jurassic, Cretaceous and Tertiary ages. The sedimentary thickness in the basin reaches about 15 km and with an area of 560000 km2, the basin is expected to contain giant oil and gas fields. It is therefore important to determine the ages and depositional environments of the petroleum source rocks. For prospective evaluation and exploration of petroleum, palynological investigations were carried out on 38 crude oil samples collected from 22 petroleum reservoirs in the Tarim Ba

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Philp, R. Paul. "Petroleum and Coal. Source Rocks." Analytical Chemistry 67, no. 12 (1995): 343–48. http://dx.doi.org/10.1021/ac00108a605.

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Hall, Lisa, Emmanuelle Grosjean, Irina Borissova, et al. "Petroleum systems analysis of the northern Houtman Sub-basin." APPEA Journal 57, no. 2 (2017): 755. http://dx.doi.org/10.1071/aj16026.

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Interpretation of newly acquired seismic data in the northern Houtman Sub-basin (Perth Basin) suggests the region contains potential source rocks similar to those in the producing Abrolhos Sub-basin. The regionally extensive late Permian–Early Triassic Kockatea Shale has the potential to contain the oil-prone Hovea Member source interval. Large Permian syn-rift half-graben, up to 10 km thick, are likely to contain a range of gas-prone source rocks. Further potential source rocks may be found in the Jurassic–Early Cretaceous succession, including the Cattamarra Coal Measures, Cadda shales and m

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Ghori, K. Ameed R. "Petroleum source rocks of Western Australia." APPEA Journal 58, no. 1 (2018): 282. http://dx.doi.org/10.1071/aj17051.

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Petroleum geochemical analysis of samples from the Canning, Carnarvon, Officer and Perth basins identified several formations with source potential, the: • Triassic Locker Shale and Jurassic Dingo Claystone of the Northern Carnarvon Basin; • Permian Irwin River Coal Measures and Carynginia Formation, Triassic Kockatea Shale and Jurassic Cattamarra Coal Measures of the Perth Basin; • Ordovician Goldwyer and Bongabinni formations, Devonian Gogo Formation and Lower Carboniferous Laurel Formation of the Canning Basin; • Devonian Gneudna Formation of the Gascoyne Platform and the Lower Permian Woor

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Sachsenhofer, R. F., S. V. Popov, S. Coric, et al. "PARATETHYAN PETROLEUM SOURCE ROCKS: AN OVERVIEW." Journal of Petroleum Geology 41, no. 3 (2018): 219–45. http://dx.doi.org/10.1111/jpg.12702.

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Bradshaw, Marita, Dianne Edwards, Chris Boreham, et al. "Geochemical underpinnings of Australia's offshore hydrocarbon prospectivity." APPEA Journal 54, no. 1 (2014): 415. http://dx.doi.org/10.1071/aj13041.

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Molecular and isotopic analyses of oils and gases can provide information on the depositional environment, maturation and age of their source rocks, and the post expulsion history of the hydrocarbons generated. Source rock analyses can determine their potential to generate hydrocarbons of varying type over specific thermal ranges, as well as demonstrating the strength of oil- or gas-to-source correlations. Together, this geochemical interpretation can provide insights about the extent of petroleum systems and can help delineate the relationships between hydrocarbon occurrences in a basin and a

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Edwards, D. S., H. I. M. Struckmeyer, M. T. Bradshaw, and J. E. Skinner. "GEOCHEMICAL CHARACTERISTICS OF AUSTRALIA'S SOUTHERN MARGIN PETROLEUM SYSTEMS." APPEA Journal 39, no. 1 (1999): 297. http://dx.doi.org/10.1071/aj98017.

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The hydrocarbons discovered to date on the southern margin of Australia have been assigned to the Austral Petroleum Supersystem based on the age of their source rocks and common tectonic history. Modelling of the source facies distribution within this supersystem using tectonic, climatic and geographic history of the southern margin basins, suggests the presence of a variety of source rocks deposited in saline playa lakes, fluvial, lacustrine, deltaic and anoxic marine environments.Testing of the palaeogeographic model using geochemical characteristics of liquid hydrocarbons confirms the three

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Troup, Alison, and Justin Gorton. "Analysis and characterisation of petroleum source rocks in Queensland." APPEA Journal 57, no. 2 (2017): 806. http://dx.doi.org/10.1071/aj16170.

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A project to improve the understanding of petroleum source rocks across Queensland’s basins was proposed through the Industry Priorities Initiative. The study has identified new source rocks, improved characterisation of known source rocks, and examined their potential as unconventional reservoirs. Round 2 of the project sampled known source rock formations in the Adavale, Bowen, Cooper and Eromanga basins, all with proven petroleum potential. Forty-eight samples from these basins were screened through Rock-Eval and total organic carbon by LECO to determine candidates for further analysis. Pyr

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Palu, Tehani, Lisa Hall, Emmanuelle Grosjean, et al. "Integrated petroleum systems analysis to understand the source of fluids in the Browse Basin, Australia." APPEA Journal 57, no. 2 (2017): 781. http://dx.doi.org/10.1071/aj16191.

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The Browse Basin is located offshore on Australia’s North West Shelf and is a proven hydrocarbon province, hosting gas with associated condensate in an area where oil reserves are typically small. The assessment of a basin’s oil potential traditionally focuses on the presence or absence of oil-prone source rocks. However, light oil can be found in basins where source rocks are gas-prone and the primary hydrocarbon type is gas-condensate. Oil rims form whenever such fluids migrate into reservoirs at pressures less than their dew point (saturation) pressure. By combining petroleum systems analys

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Guo, Jigang, Xiongqi Pang, Fengtao Guo, et al. "Petroleum generation and expulsion characteristics of Lower and Middle Jurassic source rocks on the southern margin of Junggar Basin, northwest China: implications for unconventional gas potential." Canadian Journal of Earth Sciences 51, no. 6 (2014): 537–57. http://dx.doi.org/10.1139/cjes-2013-0200.

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Jurassic strata along the southern margin of Junggar Basin are important petroleum system elements for exploration in northwest China. The Lower and Middle Jurassic source rock effectiveness has been questioned as exploration progresses deeper into the basin. These source rocks are very thick and are distributed widely. They contain a high total organic carbon composed predominantly of Type III kerogen, with some Type II kerogen. Our evaluation of source rock petroleum generation characteristics and expulsion history, including one-dimensional basin modeling, indicates that Jurassic source roc

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Chapman, R. E. "GEOLOGICAL REASONING FOR THE PETROLEUM SOURCE ROCKS OF KNOWN FIELDS." APPEA Journal 26, no. 1 (1986): 132. http://dx.doi.org/10.1071/aj85014.

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Geological reasoning for the petroleum source-migration-accumulation relationships centres around petroleum composition and its variability, water composition and its variability, and stratigraphy. For example, a field with several pools of petroleum of different compositions is likely to have been sourced from several distinct source rocks that are stratigraphically associated with the reservoir rocks. If water compositions are also variable, the conclusion is reinforced. A field with several pools of petroleum of similar quality was sourced either from similar source rocks that are stratigra

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Polyakova, I. D. "Petroleum source rocks of the Arctic region." Lithology and Mineral Resources 50, no. 1 (2015): 26–49. http://dx.doi.org/10.1134/s002449021406008x.

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HIRABAYASHI, Kenji. "Characteristics of Rock-Eval Analysis of Carbonates Source Rocks and of Petroleum Derived from Carbonate Source Rocks." Journal of the Japanese Association for Petroleum Technology 56, no. 3 (1991): 222–31. http://dx.doi.org/10.3720/japt.56.222.

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Guo, Qiang, Da Kang Zhong, Yu Lin Wang, and Yan Chun Zhong. "Characteristics of Petroleum Geology and Prediction of Favorable Areas in Jiufotang Formation, Kazuo Basin." Advanced Materials Research 361-363 (October 2011): 3–7. http://dx.doi.org/10.4028/www.scientific.net/amr.361-363.3.

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Through the research on actual measurement 106km geological profile, the hydrocarbon source rocks mainly develop the third member of Jiufotang formation, followed by the second member. There are five distribution areas where have been divided hydrocarbon source rocks thickness is more than 400m in study area. Among them, Jiufotang area has the greatest sedimentary thickness of hydrocarbon source rocks, while Siguanyingzi-Sanjiazi area has the largest area where hydrocarbon source rocks are more than 400m. Oil shale is good hydrocarbon source rock, while dark gray and black gray mudstone (or sh

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Smith, J. W., and T. D. Gilbert. "A QUEST FOR A NEW PARAMETER IN PETROLEUM EXPLORATION GEOCHEMISTRY." APPEA Journal 27, no. 1 (1987): 98. http://dx.doi.org/10.1071/aj86010.

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Primary Australian terrestrially-derived crudes are characterised by high wax and n-alkane contents. These characteristics, as determined by hydrogenation and hydrous pyrolysis, appear to be unrelated to either the chemical or petrographic compositions of Victorian brown coal lithotypes. Furthermore, since relationships between chemical and petrographic composition are obscure, a re-examination of current concepts which relate these established source rock parameters to liquid hydrocarbon generating potentials is warranted.The content of thermally stable, longer-chain, n-alkyl components in so

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Bache, Francois, Vaughan Stagpoole, Rupert Sutherland, et al. "Petroleum Prospectivity of the Tasman Frontier." APPEA Journal 54, no. 2 (2014): 520. http://dx.doi.org/10.1071/aj13093.

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The Fairway Basin lies between Australia and New Caledonia in the northern Tasman Frontier area with water depths ranging from less than 1,000–2,400 m. This basin was formed in the mid-to-late Cretaceous during the eastern Gondwana breakup and since then has received detrital and pelagic sediments. It is known for its 70,000 km2 bottom simulating reflector, interpreted as one of the world’s largest gas hydrate layers or as a regional diagenetic front. The seismic reflection data shows sedimentary thicknesses (up to 4 km) and geometries capable of trapping hydrocarbons. The authors interpreted

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Alexander, Robert, Daniel Dawson, Kieran Pierce, and Andrew Murray. "Carbon catalysed hydrogen exchange in petroleum source rocks." Organic Geochemistry 40, no. 9 (2009): 951–55. http://dx.doi.org/10.1016/j.orggeochem.2009.06.003.

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Leythaeuser, D., M. Radke, and R. G. Schaefer. "Efficiency of petroleum expulsion from shale source rocks." Nature 319, no. 6052 (1986): 427. http://dx.doi.org/10.1038/319427b0.

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Thompson-Rizer, Carolyn L., and Roger A. Woods. "Microspectrofluorescence measurements of coals and petroleum source rocks." International Journal of Coal Geology 7, no. 1 (1987): 85–104. http://dx.doi.org/10.1016/0166-5162(87)90014-0.

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Xiao, Zong Lin, Qing Qing Hao, and Zhong Min Shen. "Maturity Evolution of the Cambrian Source Rocks in the Tarim Basin." Advanced Materials Research 622-623 (December 2012): 1642–45. http://dx.doi.org/10.4028/www.scientific.net/amr.622-623.1642.

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The Tarim basin is an important petroleum basin in China, and the Cambrian strata are the major source rock successions in the basin. Integrated the source rock depositional and structural history with its geochemical and thermal parameters, this paper simulates the evolution of the Cambrian source rocks with the software Basinview. The simulation result shows that the main hydrocarbon-generation centers of the Manjiaer sag in the Tabei depression and the Tangguzibasi sag in the Southwest depression are characterized by their early hydrocarbon generation, and in the late Ordovician depositiona

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Boreham, C. J., and R. E. Summons. "NEW INSIGHTS INTO THE ACTIVE PETROLEUM SYSTEMS IN THE COOPER AND EROMANGA BASINS, AUSTRALIA." APPEA Journal 39, no. 1 (1999): 263. http://dx.doi.org/10.1071/aj98016.

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This paper presents geochemical data—gas chromatography, saturated and aromatic biomarkers, carbon isotopes of bulk fractions and individual n-alkanes—for oils and potential source rocks in the Cooper and Eromanga basins, which show clear evidence for different source-reservoir couplets. The main couplets involve Cooper Basin source and reservoir and Cooper Basin source and Eromanga Basin reservoir. A subordinate couplet involving Eromanga Basin source and Eromanga Basin reservoir is also identified, together with minor inputs from pre-Permian source rocks to reservoirs of the Cooper and Eroma

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Zhang, Jingkun, Jian Cao, Yan Wang, et al. "Geochemistry and Genesis of Oil and Gas Seeps in the Junggar Basin, NW China: Implications for Hybrid Petroleum Systems." Geofluids 2019 (August 1, 2019): 1–26. http://dx.doi.org/10.1155/2019/9732674.

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The Junggar Basin of NW China is representative in containing oil and gas seeps worldwide as there are a wide variety of oil and gas seeps over a large area. However, the genesis of these seeps remains poorly known, limiting the understanding of their implications for petroluem geology and hydrocarbon exploration. Here, we investigate 26 samples of oil and gas seeps from nine outcrops within five areas along the margins of the Junggar Basin to determine the geochemical characteristics of the hydrocarbons, constrain their genesis, and discuss future exploration strategies. Results indicate one

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Tran, Xuan Van, Huy Nhu Tran, Chuc Dinh Nguyen, et al. "Petroleum system modeling in cenozoic sediments, Block 05-1a, Nam Con Son Basin." Science and Technology Development Journal 20, K4 (2017): 91–102. http://dx.doi.org/10.32508/stdj.v20ik4.1123.

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Based on the update of exploration data the oil and gas potential within block 05-1 are studied through define the source rocks, Hydrocarbon (HC) generation, expulsion and migration, focusing on source rock Oligocene /Early Miocene and Middle Miocene; Define the accumulation of hydrocarbon in Lower Miocene targets; The results of assessments for source rock, oil sampling analysis is used to determine the relationship between in–situ oil or oil migrated from other places. The workflow of basin modeling is assigned to get output (migration pathways, volume of accumulation), as well as data calib

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Wang, Yao-Ping, Xin Zhan, Tao Luo, et al. "Oil chemometrics and geochemical correlation in the Weixinan Sag, Beibuwan Basin, South China Sea." Energy Exploration & Exploitation 38, no. 6 (2020): 2695–710. http://dx.doi.org/10.1177/0144598720950467.

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The oil–oil and oil–source rock correlations, also termed as geochemical correlations, play an essential role in the construction of petroleum systems, guidance of petroleum exploration, and definition of reservoir compartments. In this study, the problems arising from oil–oil and oil–source rock correlations were investigated using chemometric methods on oil and source rock samples from the WZ12 oil field in the Weixinan sag in the Beibuwan Basin. Crude oil from the WZ12 oil field can be classified into two genetic families: group A and B, using multidimensional scaling and principal componen

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Scotchman, Iain C., Anthony G. Doré, and Anthony M. Spencer. "Petroleum systems and results of exploration on the Atlantic margins of the UK, Faroes & Ireland: what have we learnt?" Geological Society, London, Petroleum Geology Conference series 8, no. 1 (2016): 187–97. http://dx.doi.org/10.1144/pgc8.14.

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AbstractThe exploratory drilling of 200 wildcat wells along the NE Atlantic margin has yielded 30 finds with total discovered resources of c. 4.1×109 barrels of oil equivalent (BOE). Exploration has been highly concentrated in specific regions. Only 32 of 144 quadrants have been drilled, with only one prolific province discovered – the Faroe–Shetland Basin, where 23 finds have resources totalling c. 3.7×109 BOE. Along the margin, the pattern of discoveries can best be assessed in terms of petroleum systems. The Faroe–Shetland finds belong to an Upper Jurassic petroleum system. On the east flan

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Qin, Shengfei, Guoxiao Zhou, Zheng Zhou, and Yu Yang. "Geochemical characteristics of natural gases from different petroleum systems in the Longgang gas field, Sichuan Basin, China." Energy Exploration & Exploitation 36, no. 6 (2018): 1376–94. http://dx.doi.org/10.1177/0144598718763902.

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Located in the Sichuan Basin, China, the Longgang gas field consists of three vertically developed petroleum systems with the Triassic Leikoupo Formation as a dividing interface. There is one marine petroleum system below the interface and one continental petroleum system above it. The marine petroleum system is composed of coal measures, the main source rock in the Longtan Formation, and marine reef reservoirs in the Changxing and Feixianguan formations. The continental petroleum system can also be subdivided into two sets. One is the Xujiahe petroleum system sourced from the Xujiahe coal mea

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Uruski, C., and P. Baillie. "MESOZOIC EVOLUTION OF THE GREATER TARANAKI BASIN AND IMPLICATIONS FOR PETROLEUM PROSPECTIVITY." APPEA Journal 44, no. 1 (2004): 385. http://dx.doi.org/10.1071/aj03014.

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A paradigm of New Zealand petroleum geology was that the oldest source rocks known in the region were of Cretaceous age, so any older sedimentary rocks were considered to be economic basement. Two major projects have revealed that this is not universally the case and that a Jurassic petroleum system should now be considered.Firstly, the Astrolabe 2D speculative survey, acquired by TGS-NOPEC in 2001, has revealed that a significant section underlies the traditional Cretaceous petroleum systems. Secondly, the Wakanui–1 well, drilled by Conoco, Inpex and Todd in 1999, which has recently become op

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Jackson, J., I. P. Sweet, and T. G. Powell. "STUDIES ON PETROLEUM GEOLOGY AND GEOCHEMISTRY, MIDDLE PROTEROZOIC, McARTHUR BASIN NORTHERN AUSTRALIA I: PETROLEUM POTENTIAL." APPEA Journal 28, no. 1 (1988): 283. http://dx.doi.org/10.1071/aj87022.

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Mature, rich, potential source beds and adjacent potential reservoir beds exist in the Middle Proterozoic sequence (1400-1800 Ma) of the McArthur Basin. The McArthur and Nathan Groups consist mainly of evaporitic and stromatolitic cherty dolostones interbedded with dolomitic siltstone and shale. They were deposited in interfingering marginal marine, lacustrine and fluvial environments. Lacustrine dolomitic siltstones form potential source beds, while potential reservoirs include vuggy brecciated carbonates associated with penecontemporaneous faulting and rare coarse-grained clastics. In contra

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Zhou, Tian Wei, Jun Zhang Zheng, Zhi Wei Zhang, Tie Zhuang Wu, and Jian Jun Guo. "Characteristics of Jurassic Source Rocks in the North Ustyurt Basin." Advanced Materials Research 756-759 (September 2013): 4668–71. http://dx.doi.org/10.4028/www.scientific.net/amr.756-759.4668.

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The North Ustyurt basin, located in Central Asia, is an important gas-bearing potential area, but the gas source has been the key difficult point. Based on the geo-chemical analysis of Jurassic mudstone samples and research on the petroleum geology, the qualitative evaluation was conducted, it proposed that middle Jurassic source rock was dominative hydrocarbon-generation source rock for relative high organic matter abundance and maturity compared to upper and lower Jurassic source rocks. According to the thickness distribution of dark mudstones, Kosbulak sag, Sudochi sag and Barsakelmes sag w

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Jiang, Zi-Ran, Yin-Hui Zuo, Mei-Hua Yang, Yun-Xian Zhang, and Yong-Shui Zhou. "Source rocks evaluation of the Paleogene Shahejie 3 Formation in the Dongpu Depression, Bohai Bay Basin." Energy Exploration & Exploitation 37, no. 1 (2018): 394–411. http://dx.doi.org/10.1177/0144598718802447.

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Present simulation results based on two-dimensional basin cannot obtain accurate evaluations of petroleum resources because of not combining the thermal history in the Dongpu Depression. In this paper, Shahejie 3 Formation source rocks are evaluated using the geochemical data, and based on the thermal history, the thermal maturity evolution of typical wells and the top and bottom of the Shahejie 3 Formation source rocks are modeled using BasinMod software. Results show that source rocks are mainly distributed in the Haitongji-Liutun and Qianliyuan areas, and dominated by medium to high maturit

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Petersen, Henrik I., Lars H. Nielsen, Jørgen A. Bojesen-Koefoed, Anders Mathiesen, Lars Kristensen, and Finn Dalhoff. "Evaluation of the quality, thermal maturity and distribution of potential source rocks in the Danish part of the Norwegian–Danish Basin." Geological Survey of Denmark and Greenland (GEUS) Bulletin 16 (November 28, 2008): 1–66. http://dx.doi.org/10.34194/geusb.v16.4989.

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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 Fo

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Harouna, M., and R. P. Philp. "POTENTIAL PETROLEUM SOURCE ROCKS IN THE TERMIT BASIN, NIGER." Journal of Petroleum Geology 35, no. 2 (2012): 165–85. http://dx.doi.org/10.1111/j.1747-5457.2012.00524.x.

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Brooks, J., C. Cornford, and R. Archer. "The role of hydrocarbon source rocks in petroleum exploration." Geological Society, London, Special Publications 26, no. 1 (1987): 17–46. http://dx.doi.org/10.1144/gsl.sp.1987.026.01.02.

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Powell, T. G. "Petroleum geochemistry and depositional setting of lacustrine source rocks." Marine and Petroleum Geology 3, no. 3 (1986): 200–219. http://dx.doi.org/10.1016/0264-8172(86)90045-0.

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Boreham, C. J. "ORIGIN OF PETROLEUM IN THE BOWEN AND SURAT BASINS: GEOCHEMISTRY REVISITED." APPEA Journal 35, no. 1 (1995): 579. http://dx.doi.org/10.1071/aj94036.

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A detailed regional geochemical study of over 70 oils and condensates, eleven natural gases and over a hundred core samples from potential source rocks enable resolution of the generation and migration history of petroleum in the Bowen and Surat Basins. Biomarker analysis confirms a pre-Jurassic source for the petroleum. Stable carbon-isotope analysis further indicated a Permian-sourced petroleum and was able to differentiate a very minor and localised Triassic source contribution. The dominant source for the petroleum is terrestrial land plants as well as a minor contribution from bacteria an

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Thomas, Charmaine M. "Permian source rocks of the onshore and nearshore Carnarvon Basin." APPEA Journal 61, no. 2 (2021): 726. http://dx.doi.org/10.1071/aj20199.

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A new sampling program of Permian potential source rocks was undertaken to improve knowledge of the Permian petroleum prospectivity in new parts of the Southern Carnarvon and inboard Northern Carnarvon Basins. Presented here are new Rock-Eval data from previously unsampled wells, drillholes and outcrop and new infill sampling between existing data points. Kerogen assemblages of selected intervals were also determined from palynofacies analysis or organic petrography, which suggests the good Permian source rocks are generally dominated by gas-prone kerogens. Possibly terrestrial-derived oil-pro

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Troup, Alison, and Sally Edwards. "Source rock characterisation of under-explored regions of Queensland." APPEA Journal 56, no. 2 (2016): 580. http://dx.doi.org/10.1071/aj15086.

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Historically, petroleum exploration in Queensland has focused on the Bowen-Surat and Cooper-Eromanga basins, with only cursory examination of other basins across the state. As part of the Queensland Industry Priorities Initiative, two projects (Round 1 and 2) were submitted to the Geological Survey of Queensland (GSQ) to examine the geochemical characteristics of potential petroleum source rocks throughout Queensland. The analysis conducted provides a better understanding of generative potential for petroleum, and predicts the timing, volume, composition, and physical state of hydrocarbons ret

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Tang, Youjun, Meijun Li, Qiuge Zhu, et al. "Geochemical characteristics and origin of hydrocarbons in the Mesoproterozoic reservoirs in the Liaoxi Depression, NE China." Energy Exploration & Exploitation 38, no. 2 (2019): 333–47. http://dx.doi.org/10.1177/0144598719862922.

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Oil reservoirs have been discovered in the Mesoproterozoic strata in the Liaoxi Depression, NE China. In order to determine the source of oil shows of the Mesoproterozoic Gaoyuzhuang Formation and their organic geochemical characteristics, eight source rocks and reservoir cores from the Mesoproterozoic Gaoyuzhuang Formation and four source rocks from the overlying Middle Jurassic Haifanggou Formation were geochemically analysed. The distribution patterns of normal alkanes, acyclic isoprenoids, hopanes, steranes and triaromatic steroids of the Mesoproterozoic hydrocarbons from Well N-1 are cons

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Bojesen-Koefoed, Jørgen A., Hans Peter Nytoft, and Flemming G. Christiansen. "Age of oils in West Greenland: was there a Mesozoic seaway between Greenland and Canada?" Geological Survey of Denmark and Greenland (GEUS) Bulletin 4 (July 20, 2004): 49–52. http://dx.doi.org/10.34194/geusb.v4.4783.

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For many years the existence of an oil-prone source rock off West Greenland was challenged by industry. But since 1992 when active oil seeps were found onshore West Greenland on the Nuussuaq peninsula (Fig. 1; Christiansen et al. 1996; Bojesen-Koefoed et al.1999), the question has changed focus to the age, distribution and potential of the source rock. Five different oils – each with their own characteristics – have been reported by the Geological Survey of Denmark and Greenland (GEUS). One of these, a typical marine shalederived oil with a possible regional distribution, is known as the Itill

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Price, Leigh C., and Jerry L. Clayton. "Extraction of whole versus ground source rocks: Fundamental petroleum geochemical implications including oil-source rock correlation." Geochimica et Cosmochimica Acta 56, no. 3 (1992): 1213–22. http://dx.doi.org/10.1016/0016-7037(92)90057-p.

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Tulan, Emilia, Michaela S. Radl, Reinhard F. Sachsenhofer, Gabor Tari, and Jakub Witkowski. "Hydrocarbon source rock potential of Miocene diatomaceous sequences in Szurdokpüspöki (Hungary) and Parisdorf/Limberg (Austria)." Austrian Journal of Earth Sciences 113, no. 1 (2020): 24–42. http://dx.doi.org/10.17738/ajes.2020.0002.

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AbstractDiatomaceous sediments are often prolific hydrocarbon source rocks. In the Paratethys area, diatomaceous rocks are widespread in the Oligo-Miocene strata. Diatomites from three locations, Szurdokpüspöki (Hungary) and Limberg and Parisdorf (Austria), were selected for this study, together with core materials from rocks underlying diatomites in the Limberg area. Bulk geochemical parameters (total organic carbon [TOC], carbonate and sulphur contents and hydrogen index [HI]) were determined for a total of 44 samples in order to study their petroleum potential. Additionally, 24 samples were

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Cooles, G. P., A. S. Mackenzie, and R. J. Parkes. "Non-hydrocarbons of significance in petroleum exploration: volatile fatty acids and non-hydrocarbon gases." Mineralogical Magazine 51, no. 362 (1987): 483–93. http://dx.doi.org/10.1180/minmag.1987.051.362.03.

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AbstractNon-hydrocarbon gas species (CO2, N2, H2) are locally important in exploration for gas, and there is a growing body of evidence that acid water originating in shales materially affects the diagenesis of nearby sandstones. These gases have been studied by analysing the products of closed-vessel hydrous pyrolysis of known petroleum source rocks, and comparing the results with field observations. Alteration of petroleum source rocks at temperatures >250°C yields a significant amount of non-hydrocarbon components. Ethanoate and higher acid anions are liberated in substantial quantities;

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Hallmann, C. O. E., K. R. Arouri, D. M. McKirdy, and L. Schwark. "A NEW PERSPECTIVE ON EXPLORING THE COOPER/EROMANGA PETROLEUM PROVINCE—EVIDENCE OF OIL CHARGING FROM THE WARBURTON BASIN." APPEA Journal 46, no. 1 (2006): 261. http://dx.doi.org/10.1071/aj05015.

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The history of petroleum exploration in central Australia has been enlivened by vigorous debate about the source(s) of the oil and condensate found in the Cooper/Eromanga basin couplet. While early workers quickly recognized the source potential of thick Permian coal seams in the Patchawarra and Toolachee Formations, it took some time for the Jurassic Birkhead Formation and the Cretaceous Murta Formation to become accepted as effective source rocks. Although initially an exploration target, the Cambrian sediments of the underlying Warburton Basin subsequently were never seriously considered to

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