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Journal articles on the topic 'Coal maturation'

Author: Grafiati

Published: 4 June 2021

Last updated: 15 February 2022

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1

FERNANDES, P., G. LOPES, G. MACHADO, Z. PEREIRA, and B. RODRIGUES. "Superimposed thermal histories in the southern limit of the Ossa Morena Zone – Portugal." Geological Magazine 154, no. 3 (April 22, 2016): 591–608. http://dx.doi.org/10.1017/s0016756816000248.

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AbstractThe Mississippian volcano-sedimentary complex in the Toca da Moura – Cabrela areas represents remnants of intra-volcanic marine sedimentary basins, formed during the collision between the Ossa Morena Zone with the South Portuguese Zone. These rock units are unconformably overlain by the Pennsylvanian intramontane coal-bearing Santa Susana Basin. Vitrinite reflectance determinations from rocks of these two basins indicate two episodes of thermal maturation. During the first episode, the Toca da Moura – Cabrela volcano-sedimentary complexes attained high maturation levels, equivalent to anthracite coal rank (3.0–3.5% Roran), which pre-dates the middle Moscovian Santa Susana Basin. The Santa Susana Basin attained moderate maturation levels equivalent to bituminous coal rank (1.35–1.5% Roran) recording a second episode of thermal maturation. Here, peak thermal conditions did not overprint the first maturation episode. The observed effects of magmatic intrusion on the thermal maturity and the lack of any increase in vitrinite reflectance with depth through c. 400 m of section in borehole SDJ-1 indicate high geothermal gradients during the first maturation episode. A contemporaneous magmatic event associated with the c. 335–320 Ma Cuba-Alvito Gabbros/Diorites of the Beja Massif was the possible cause for the high geothermal gradients postulated for the first maturation episode. Burial under a post-upper Moscovian sedimentary cover was the most likely process to account for the maturation levels determined for the Santa Susana Basin and for the second episode of thermal maturation.

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2

Monthioux, M., and P. Landais. "Natural and artificial maturation of coal: Hopanoid stereochemistry." Chemical Geology 75, no. 3 (March 1989): 209–26. http://dx.doi.org/10.1016/0009-2541(89)90119-8.

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3

Mullins, Oliver C., Sudipa Mitra-Kirtley, Jan Van Elp, and Stephen P. Cramer. "Molecular Structure of Nitrogen in Coal from XANES Spectroscopy." Applied Spectroscopy 47, no. 8 (August 1993): 1268–75. http://dx.doi.org/10.1366/0003702934067991.

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Five major nitrogen chemical structures, present in coals of varying ranks, have been quantitatively determined with the use of nitrogen x-ray absorption near-edge spectroscopy (XANES). Similar studies of the sulfur chemical structures of coals have been performed for the last ten years; nitrogen studies on these fossil-fuel samples have only recently been realized. XANES spectra of coals exhibit several distinguishable resonances which can be correlated with characteristic resonances of particular nitrogen chemical structures, thereby facilitating analysis of these complicated systems. Many model compounds have been examined; for some, the relative peak positions are explained in terms of the orbital description of the lone pair of electrons. All features in the XANES spectra of coals have been accounted for; thus, all the major structural groups of nitrogen present in coals have been determined. A wide variety of aromatic nitrogen compounds is found in the coals; no evidence of saturated amine is found. Pyrroles, pyridines, pyridones, and aromatic amines are found in coal; of these, pyrrolic structures are the most prevalent. Pyridine nitrogen is prevalent in all except low-rank coals. The low pyridine content in low-rank (high-oxygen) coals correlates with a large pyridone content. This observation suggests that, with increasing maturation of coal, the pyridone loses its oxygen and is transformed into pyridine. Aromatic amines are present at low levels in coals of all rank. The spectral effects of aromatic amines are shown by comparing the XANES spectra of coal and petroleum asphaltenes.

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4

MEGURO, Seitaro. "A view of the coal/water slurry technological maturation." Journal of the Fuel Society of Japan 65, no. 11 (1986): 876–92. http://dx.doi.org/10.3775/jie.65.11_876.

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5

Kitamura, Manami, Hideki Mukoyoshi, Patrick M. Fulton, and Takehiro Hirose. "Coal maturation by frictional heat during rapid fault slip." Geophysical Research Letters 39, no. 16 (August 16, 2012): n/a. http://dx.doi.org/10.1029/2012gl052316.

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6

Saxby, J. D., P. Chatfield, G. H. Taylor, J. D. Fitzgerald, I. R. Kaplan, and S. T. Lu. "Effect of clay minerals on products from coal maturation." Organic Geochemistry 18, no. 3 (May 1992): 373–83. http://dx.doi.org/10.1016/0146-6380(92)90078-c.

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7

Monthioux, M., and P. Landais. "Natural and artificial maturation of coal: Non-hopanoid biomarkers." Chemical Geology 77, no. 1 (September 1989): 71–85. http://dx.doi.org/10.1016/0009-2541(89)90017-x.

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8

Powell, T. G., and C. J. Boreham. "PETROLEUM GENERATION AND SOURCE ROCK ASSESSMENT IN TERRIGENOUS SEQUENCES: AN UPDATE." APPEA Journal 31, no. 1 (1991): 297. http://dx.doi.org/10.1071/aj90023.

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Analytical pyrolysis and sealed tube pyrolysis at low temperatures have been used to study the timing and petroleum generating capacity of selected Permian through Tertiary coals and carbonaceous shales in relation to their petrographic and elemental composition. The results show that judicious application of flash pyrolysis techniques in conjunction with more conventional procedures are essential for effective source rock assessment in terrigenous source rocks, particularly in those of lower quality.Although the petroleum potential of the samples follows the broad trends in petrographic composition established for Australian coals, that is, relative proportions of vitrinite, inertinite and liptinite, there is much variation which cannot be explained petrographically at the maceral group level. Furthermore, there is no simple relationship between pyrolytic hydrocarbon yield from terrigenous kerogens and overall elemental composition. The yield and composition of pyrolysable normal hydrocarbons varies widely depending on the nature and amount of liptinite macerals, particularly for samples with Hydrogen Indices below 300. Liptinite-poor (Mass balance calculations based on Rock-Eval analyses of samples from the Jurassic Walloon Coal Measures show that the maximum oil formation occurs over a very narrow maturation window from 0.8 to 1.0 per cent Ro, although small amounts of oil may be generated at lower maturation levels. The gas to oil ratio of the generated hydrocarbons is constant up to a reflectance level of 1.0 per cent Ro, where upon the proportion of gas increases rapidly. The low quality Permian source rocks from the Cooper Basin have a lower ratio of labile to refractory kerogen than the Jurassic and Tertiary examples. As a result, the gas to oil ratio of hydrocarbons formed in the oil window is higher and the oil potential appears to be exhausted at an earlier stage of maturation. Efficient migration of hydrocarbons from Permian sediments in the Cooper Basin also appears to occur at a relatively early stage of maturation compared with the Jurassic Walloon Coal Measures.

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9

Han, Zhiwen, Qi Yang, and Zhigui Pang. "Artificial maturation study of a humic coal and a torbanite." International Journal of Coal Geology 46, no. 2-4 (May 2001): 133–43. http://dx.doi.org/10.1016/s0166-5162(01)00018-0.

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10

Yao, Suping, Chunyan Xue, Wenxuan Hu, Jian Cao, and Chuanlun Zhang. "A comparative study of experimental maturation of peat, brown coal and subbituminous coal: Implications for coalification." International Journal of Coal Geology 66, no. 1-2 (February 2006): 108–18. http://dx.doi.org/10.1016/j.coal.2005.07.007.

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11

Hou, Zi Ming, Hong Wen Deng, and Ming Hui Liu. "Preliminary Source Rock Evaluation of Lower-Cretaceous Coal-Measures Strata in Hulin Basin in Northeastern China." Advanced Materials Research 968 (June 2014): 194–97. http://dx.doi.org/10.4028/www.scientific.net/amr.968.194.

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According to the thermal decomposition achievement of coal shale and coal samples, which are gathered from the Lower-Cretaceous coal-measure strata of Hulin basin, the organic matter abundance, type and maturation have been analyzed with TOC, S1+ S2, Hydrogen Index, content of maceral, Tmax , Ro. The result indicates that the organic abundance of coal shale and coal in Qihulin formation is average ,kerogen type is type III and their thermal evolution is over mature . The organic abundance of coal shale in Yunshan formation is general to better while the coal’s organic abundance is from better to best, they are both type III kerogen, and their thermal evolution is mature. The above analysis indicates that the hydrocarbon generating potential is limited in the Lower-Cretaceous coal-measure strata of Hulin basin while coal-measure source rocks in the Yunshan formation have good hydrocarbon generating potential.

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12

Landais, P., and M. Monthioux. "Closed system pyrolysis : an efficient technique for simulating natural coal maturation." Fuel Processing Technology 20 (December 1988): 123–32. http://dx.doi.org/10.1016/0378-3820(88)90013-6.

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13

Burnham, Alan K. "Historical Perspective on the Maturation of Modeling Coal and Kerogen Pyrolysis." Energy & Fuels 35, no. 13 (June 11, 2021): 10451–60. http://dx.doi.org/10.1021/acs.energyfuels.1c01337.

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14

Li, Pengpeng, Shixin Zhou, Xiaodong Zhang, Jing Li, Shuo Zhang, Anqi Hou, and Chen Guo. "Analysis on correlation between nanopores and coal compositions during thermal maturation process." Marine and Petroleum Geology 121 (November 2020): 104608. http://dx.doi.org/10.1016/j.marpetgeo.2020.104608.

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15

Teerman, S. C., and R. J. Hwang. "Evaluation of the liquid hydrocarbon potential of coal by artificial maturation techniques." Organic Geochemistry 17, no. 6 (January 1991): 749–64. http://dx.doi.org/10.1016/0146-6380(91)90019-g.

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16

Butala, Steven J. M., Juan Carlos Medina, Terrence Q. Taylor, Calvin H. Bartholomew, and Milton L. Lee. "Mechanisms and Kinetics of Reactions Leading to Natural Gas Formation during Coal Maturation." Energy & Fuels 14, no. 2 (March 2000): 235–59. http://dx.doi.org/10.1021/ef990076k.

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17

Wang, Chunjiang, Yanqing Xia, and Binjie Luo. "Thermal-induced polycondensation of soluble organic matter in coal of lower maturation stage." Chinese Science Bulletin 43, no. 6 (March 1998): 501–4. http://dx.doi.org/10.1007/bf02883820.

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18

Chyi, L. L., R. G. Barnett, A. E. Burford, T. J. Quick, and R. J. Gray. "Coalification patterns of the Pittsburgh coal: their origin and bearing on hydrocarbon maturation." International Journal of Coal Geology 7, no. 1 (January 1987): 69–83. http://dx.doi.org/10.1016/0166-5162(87)90013-9.

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19

Salmon, Elodie, Adri C. T. van Duin, François Lorant, Paul-Marie Marquaire, and William A. Goddard. "Early maturation processes in coal. Part 2: Reactive dynamics simulations using the ReaxFF reactive force field on Morwell Brown coal structures." Organic Geochemistry 40, no. 12 (December 2009): 1195–209. http://dx.doi.org/10.1016/j.orggeochem.2009.09.001.

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20

Fattah, R. Abdul, J. M. Verweij, N. Witmans, and J. H. ten Veen. "Reconstruction of burial history, temperature, source rock maturity and hydrocarbon generation in the northwestern Dutch offshore." Netherlands Journal of Geosciences - Geologie en Mijnbouw 91, no. 4 (December 2012): 535–54. http://dx.doi.org/10.1017/s0016774600000378.

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Abstract3D basin modelling is used to investigate the history of maturation and hydrocarbon generation on the main platforms in the northwestern part of the offshore area of the Netherlands. The study area covers the Cleaverbank and Elbow Spit Platforms. Recently compiled maps and data are used to build the input geological model. An updated and refined palaeo water depth curve and newly refined sediment water interface temperatures (SWIT) are used in the simulation. Basal heat flow is calculated using tectonic models. Two main source rock intervals are defined in the model, Westphalian coal seams and pre-Westphalian shales, which include Namurian and Dinantian successions. The modelling shows that the pre-Westphalian source rocks entered the hydrocarbon generation window in the Late Carboniferous. In the southern and central parts of the study area, the Namurian started producing gas in the Permian. In the north, the Dinantian source rocks appear to be immature. Lower Westphalian sediments started generating gas during the Upper Triassic. Gas generation from Westphalian coal seams increased during the Paleogene and continues in present-day. This late generation of gas from Westphalian coal seams is a likely source for gas accumulations in the area.Westphalian coals might have produced early nitrogen prior to or during the main gas generation occurrence in the Paleogene. Namurian shales may be a source of late nitrogen after reaching maximum gas generating phase in the Triassic. Temperatures reached during the Mid Jurassic were sufficiently high to allow the release of non-organic nitrogen from Namurian shales.

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21

Salmon, Elodie, Françoise Behar, François Lorant, Patrick G. Hatcher, and Paul-Marie Marquaire. "Early maturation processes in coal. Part 1: Pyrolysis mass balance and structural evolution of coalified wood from the Morwell Brown Coal seam." Organic Geochemistry 40, no. 4 (April 2009): 500–509. http://dx.doi.org/10.1016/j.orggeochem.2009.01.004.

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22

Gayer, R. A., J. Pešek, I. Sýkorová, and P. Valterová. "Coal clasts in the upper Westphalian sequence of the South Wales coal basin: implications for the timing of maturation and fracture permeability." Geological Society, London, Special Publications 109, no. 1 (1996): 103–20. http://dx.doi.org/10.1144/gsl.sp.1996.109.01.08.

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23

Radke, Matthias, and Helmut Willsch. "Generation of alkylbenzenes and benzo[b]thiophenes by artificial thermal maturation of sulfur-rich coal." Fuel 72, no. 8 (August 1993): 1103–8. http://dx.doi.org/10.1016/0016-2361(93)90316-t.

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24

Glikson, M., and J. A. K. Owen. "A New Ireland coal and associated sediments: hydrocarbon generation from pollen exines at low maturation." Journal of Southeast Asian Earth Sciences 1, no. 4 (January 1986): 221–34. http://dx.doi.org/10.1016/0743-9547(86)90017-6.

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25

Miyazaki, S., and R. J. Korsch. "COALBED METHANE RESOURCES IN THE PERMIAN OF EASTERN AUSTRALIA AND THEIR TECTONIC SETTING." APPEA Journal 33, no. 1 (1993): 161. http://dx.doi.org/10.1071/aj92013.

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The Bowen and Sydney Basins in eastern Australia contain vast coal resources which provide a source for coalbed methane. Through studies of the spatial and temporal distribution of the sedimentary packages, the structural geometry and tectonic setting of the sedimentary packages, and the maturation and burial history, the Australian Geological Survey Organisation (AGSO) is mapping the distribution and structural styles of the sources of methane, in particular, the Late Permian coal measures. AGSO's results from the Bowen Basin show at least two distinctly different structural styles of potential targets for coalbed methane drainage: on the Comet Ridge, the Permian coal measures are essentially subhorizontal and tectonically undisturbed, whereas in the western Taroom Trough, the coal measures are folded into a series of anticlines, each of which occurs above a thrust fault which in turn forms part of an imbricate thrust fan. Both of these styles occur at depths of less than 1000 m.Calculations by the Bureau of Resource Sciences (BRS) indicate that the inferred coalbed methane resources-in-place are 62 trillion cubic feet (1760 billion m3) for Australia, in which the Bowen and Sydney Basins are currently the only potential provinces of coalbed methane. The low permeability of the coal seams hinders attempts to utilise this vast amount of energy resources.Further exploration is necessary to delineate commercially feasible areas. This delineation is the only process that will be able to determine demonstrated coalbed methane resources.

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26

Mazumder, Saikat, Amit A. Karnik, and Karl-Heinz A. A. Wolf. "Swelling of Coal in Response to CO2 Sequestration for ECBM and Its Effect on Fracture Permeability." SPE Journal 11, no. 03 (September 1, 2006): 390–98. http://dx.doi.org/10.2118/97754-pa.

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Summary The "swelling" of coal by a penetrant refers to an increase in the volume occupied by the coal as a result of the viscoelastic relaxation of its highly crosslinked macromolecular structure. Projects relating to CO2 sequestration in coal seams suffer a serious setback in terms of injectivity loss resulting from the swelling of coal. Volumetric swelling associated with CO2 sorption on coal has a significant influence on the fracture porosity and permeability of the coal. Two coal samples differing in rank were used for volumetric strain measurements. With CO2-, the high-rank Selar Cornish coal showed a maximum volumetric strain of 1.48% corresponding to an average pore pressure of 13 MPa. A matrix swelling coefficient (Cm) of 1.77× 10-4 MPa-1 was calculated for this Selar Cornish coal. The low-rank Warndt Luisenthal coal exhibited higher strain of 1.6%, and a matrix swelling coefficient (Cm) of 8.98×10-5 MPa-1 was calculated. The rank dependence of swelling holds true in this set of experiments. Repeat volumetric strain measurement on the same Warndt Luisenthal coal core shows higher volumetric strain values for all pressure steps. A volumetric strain of 1.9% corresponding to a mean pore pressure of 14 MPa was measured. This confirms the process of sequential swelling. A unique feature of this work is that real-time permeability measurements were done under unconstrained conditions. Permeabilities were measured, reducing the pore pressure from 16 to 1 MPa at constant flow rate. Although measured permeability increased with increasing pore pressure under unconstrained swelling, in-situ permeability will actually decrease because of fracture closure in a constrained coal. To validate the permeability swelling relationship, both permeability measurements under unconstrained conditions and volumetric strain measurements were used. Introduction Maturation of coalbed methane (CBM) production operations in some basins, the emergence of injection schemes for enhanced coalbed methane (ECBM), and carbon sequestration of greenhouse gases has led to renewed focus on the behavior of coalbed reservoir properties under these conditions. Cleat permeability of coal is the most important parameter for coalbed methane production. Being normal to the bedding plane and orthogonal to each other, the face and butt cleats in coal seams are usually subvertically oriented. Thus, changes in the cleat permeability are primarily controlled by the prevailing effective horizontal stresses that act across the cleats, rather than the effective vertical stress, defined as the difference between the overburden stress and pore pressure (Harpalani and Chen 1997). Coal swelling accompanying CO2 sorption would decrease the permeability of the coal as the volume increase is compensated within the fracture porosity.

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27

Privalov, Vitaliy, Jacques Pironon, Philippe de Donato, Raymond Michels, Christophe Morlot, and Alain Izart. "Natural Fracture Systems in CBM Reservoirs of the Lorraine–Saar Coal Basin from the Standpoint of X-ray Computer Tomography." Environmental Sciences Proceedings 5, no. 1 (December 1, 2020): 12. http://dx.doi.org/10.3390/iecg2020-08772.

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The Lorraine–Saar Basin is one of the largest geologically and commercially important Paleozoic coal-bearing basins in Western Europe and has considerable coal reserves in numerous coal beds. The basin stands out due to its sedimentary column of up to 6 km and its inversion, resulting in Paleozoic low-amplitude erosion at around 750 m (French part of the basin) and pre-Mesozoic (Permian) erosion between 1800 and 3000 m (the Saar coalfield or German part of the basin). Thermal maturation of organic matter in sedimentary clastic rocks and coal seams has led to the formation of prolific coalbed methane (CBM) plays in many domains throughout the Carboniferous Westphalian and Stephanian sequences. Coal mines here are no longer operated to produce coal; however, methane generated in “dry gas window” compartments at a depth exceeding 3.5 km has escaped here via several major faults and fracture corridors forming “sweet spot” sites. Faults and a dense network of tectonic fractures together with post-mining subsidence effects also increased the permeability of massive coal-bearing and provided pathways for the breathing of environmentally hazardous mine gases. Nearly all CBM plays can be classified as naturally fractured reservoirs. The Lorraine–Saar Basin is not excluded, indeed, because of the experience of geological surveys during extensive coal-mining in the past. The knowledge of geometrical features of fracture patterns is a crucial parameter for determining the absolute permeability of a resource play, its kinematics environment, and further reservoir simulation. The main focus of this contribution is to gain an insight into the style and structural trends of natural cleat patterns in the basin based on the results of X-ray computer tomography (CT) to ensure technical decisions for efficient exploration of CBM reservoirs. To explore the architecture of solid coal samples, we used X-ray CT of a coal specimen collected from Westphalian D coal from exploratory well Tritteling 1. The studied coal specimen and its subvolumes were inspected in three series of experiments. At different levels of CT resolutions, we identified two quasi-orthogonal cleat systems including a smooth-sided face cleat of tensile origin and a curvilinear shearing butt cleat. The inferred cleat patterns possess features of self-similarity and align with directional stresses. Results of the treatment of obtained cleat patterns in terms of their connectivity relationship allowed the presence of interconnected cleat arrays to be distinguished within studied samples, potentially facilitating success in CBM extraction projects.

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28

Garcia-Vallès, M., M. Vendrell-Saz, and T. Pradell-Cara. "Organic geochemistry (Rock-Eval) and maturation rank of the Garumnian coal in the Central Pyrenees (Spain)." Fuel 79, no. 5 (April 2000): 505–13. http://dx.doi.org/10.1016/s0016-2361(99)00150-7.

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29

Vuković, Nikola, Dragana Životić, João Graciano Mendonça Filho, Tamara Kravić-Stevović, Mária Hámor-Vidó, Joalice de Oliveira Mendonça, and Ksenija Stojanović. "The assessment of maturation changes of humic coal organic matter — Insights from closed-system pyrolysis experiments." International Journal of Coal Geology 154-155 (January 2016): 213–39. http://dx.doi.org/10.1016/j.coal.2016.01.007.

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30

Piedad-Sánchez, Noé, Luis Martínez, Alain Izart, Isabel Suárez-Ruiz, Marcel Elie, and Cédric Menetrier. "Artificial maturation of a high volatile bituminous coal from Asturias (NW Spain) in a confined pyrolysis system." Journal of Analytical and Applied Pyrolysis 74, no. 1-2 (August 2005): 61–76. http://dx.doi.org/10.1016/j.jaap.2004.12.012.

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31

Piedad-Sánchez, Noé, Luis Martínez, Alain Izart, Isabel Suárez-Ruiz, Marcel Elie, Cédric Menetrier, and Frederic Lannuzel. "Artificial maturation of a high volatile bituminous coal from Asturias (NW Spain) in a confined pyrolysis system." Journal of Analytical and Applied Pyrolysis 74, no. 1-2 (August 2005): 77–87. http://dx.doi.org/10.1016/j.jaap.2004.12.013.

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32

Sijie, Han, Sang Shuxun, Zhou Peiming, Jia Jinlong, and Liang Jingjing. "Burial history and the evolution of hydrocarbon generation in Carboniferous-Permian coal measures within the Jiyang super-depression, China." Earth Sciences Research Journal 24, no. 4 (January 26, 2021): 397–408. http://dx.doi.org/10.15446/esrj.v24n4.63220.

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In the Jiyang Sub-basin, Carboniferous-Permian (C-P) coal-measure source rocks have experienced complex multi-stage tectonics and therefore have a complex history of hydrocarbon generation. Because these coal measures underwent multi-stage burial and exhumation, they are characterized by various burial depths. In this study, we used the basin modeling technique to analyze the relationship between burial history and hydrocarbon generation evolution. The burial, thermal and maturity histories of C-P coals were reconstructed, including primary hydrocarbon generation, stagnation, re-initiation, and peak secondary hydrocarbon generation. The secondary hydrocarbon generation stage within this reconstruction was characterized by discontinuous generation and geographical differences in maturity due to the coupled effects of depth and a delay of hydrocarbon generation. According to the maturity history and the delay effect on secondary hydrocarbon generation, we concluded that the threshold depth of secondary hydrocarbon generation in the Jiyang Sub-basin occurred at 2,100 m during the Yanshan epoch (from 205 Ma to 65 Ma) and at 3,200 m during the Himalayan period (from 65 Ma to present). Based on depth, residual thickness, maturity, and hydrocarbon-generating intensity, five favorable areas of secondary hydrocarbon generation in the Jiyang Sub-basin were identified, including the Chexi areas, Gubei-Luojia areas, Yangxin areas, the southern slope of the Huimin depression and southwest of the Dongying depression. The maximum VRo/burial depth (%/km) occurred in the Indosinian epoch as the maximum VRo/time (%/100Ma) happened in the Himalayan period, indicating that the coupling controls of temperature and subsidence rate on maturation evolution play a significant role in the hydrocarbon generation evolution. A higher temperature and subsidence rate can both enhance the hydrocarbon generation evolution.

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33

Marshall, John F., Chao Shing Lee, Douglas C. Ramsay, and Aidan M. G. Moore. "TECTONIC CONTROLS ON SEDIMENTATION AND MATURATION IN THE OFFSHORE NORTH PERTH BASIN." APPEA Journal 29, no. 1 (1989): 450. http://dx.doi.org/10.1071/aj88037.

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The major tectonic and stratigraphic elements of the offshore North Perth Basin have been delineated from regional BMR multichannel seismic reflection lines, together with industry seismic and well data. This analysis reveals that three sub- basins, the Edel, Abrolhos and Houtman Sub- basins, have formed as a result of three distinct episodes of rifting within the offshore North Perth Basin during the Early Permian, Late Permian and Late Jurassic respectively. During this period, rifting has propagated from east to west, and has culminated in the separation of this part of the Australian continent from Greater India.The boundaries between the sub- basins and many structures within individual sub- basins are considered to have been produced by strike- slip or oblique- slip motion. The offshore North Perth Basin is believed to be a product of transtension, possibly since the earliest phase of rifting. This has culminated in separation and seafloor spreading by oblique extension along the Wallaby Fracture Zone to form a transform passive continental margin.This style of rifting and extension has produced relatively thin syn- rift sequences, some of which have been either partly or completely removed by erosion. While the source- rock potential of the syn- rift phase is limited, post- rift marine transgressional phases and coal measures do provide adequate and relatively widespread source rocks for hydrocarbon generation. Differences in the timing of rifting across the basin have resulted in a maturation pattern whereby mature sediments become younger to the west.

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34

Michels, R., V. Burkle, L. Mansuy, E. Langlois, O. Ruau, and P. Landais. "Role of Polar Compounds as Source of Hydrocarbons and Reactive Medium during the Artificial Maturation of Mahakam Coal." Energy & Fuels 14, no. 5 (September 2000): 1059–71. http://dx.doi.org/10.1021/ef000046d.

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35

Obaje, N. G., I. I. Funtua, B. Ligouis, and S. I. Abaa. "Maceral associations, organic maturation and coal-derived hydrocarbon potential in the Cretaceous Awgu Formation, Middle Benue Trough, Nigeria." Journal of African Earth Sciences 23, no. 1 (July 1996): 89–94. http://dx.doi.org/10.1016/s0899-5362(96)00054-1.

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36

Mansuy, L., P. Landais, and O. Ruau. "Importance of the Reacting Medium in Artificial Maturation of a Coal by Confined Pyrolysis. 1. Hydrocarbons and Polar Compounds." Energy & Fuels 9, no. 4 (July 1995): 691–703. http://dx.doi.org/10.1021/ef00052a018.

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37

Mansuy, L., and P. Landais. "Importance of the reacting medium in artificial maturation of a coal by confined pyrolysis. 2. Water and polar compounds." Energy & Fuels 9, no. 5 (September 1995): 809–21. http://dx.doi.org/10.1021/ef00053a012.

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38

Mansuy, L., and P. Landais. "Importance of the reacting medium in artificial maturation of a coal by confined pyrolysis. 2. Water and polar compounds." Fuel and Energy Abstracts 37, no. 3 (May 1996): 170. http://dx.doi.org/10.1016/0140-6701(96)88337-8.

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39

Glombitza, Clemens, Kai Mangelsdorf, and Brian Horsfield. "Maturation related changes in the distribution of ester bound fatty acids and alcohols in a coal series from the New Zealand Coal Band covering diagenetic to catagenetic coalification levels." Organic Geochemistry 40, no. 10 (October 2009): 1063–73. http://dx.doi.org/10.1016/j.orggeochem.2009.07.008.

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40

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. Pyrolysis gas chromatography was conducted on selected samples (n = 15) to understand the bulk chemical signatures of kerogens with fluids extracted to derive isotopic and biomarker signatures. Organic petrology (n = 11) examined kerogen components and reflectance. Immature samples were analysed for bulk kinetics (n = 10) to determine the stability of kerogens while some were sent for compositional kinetics (n = 7), to predict the gas to oil ratio (GOR) and saturation pressure. Some more mature samples were sent for late gas analysis (n = 6) to understand hydrocarbon generation at later stages of thermal maturation. The results indicate that the marls in the Bury Limestone may have promising potential, that the Permian coals are the principal source rocks in the Cooper and Bowen basins and that the coals and mudstones of the Birkhead Formation have potential to generate. High production index values were noted in the Bury Limestone, as well as coal and mudstone samples from the Cooper and Bowen basins, suggesting that some of these source rocks also have good retention capabilities.

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41

Galasso, Francesca, Paulo Fernandes, Giovanni Montesi, João Marques, Amalia Spina, and Zélia Pereira. "Thermal history and basin evolution of the Moatize - Minjova Coal Basin (N'Condédzi sub-basin, Mozambique) constrained by organic maturation levels." Journal of African Earth Sciences 153 (May 2019): 219–38. http://dx.doi.org/10.1016/j.jafrearsci.2019.02.020.

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42

Boreham, C. J., and T. G. Powell. "Variation in pyrolysate composition of sediments from the Jurassic Walloon Coal Measures, eastern Australia as a function of thermal maturation." Organic Geochemistry 17, no. 6 (January 1991): 723–33. http://dx.doi.org/10.1016/0146-6380(91)90016-d.

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43

Cruz-Ceballos, Luis Felipe, Mario García-González, Luis Enrique Cruz-Guevara, and Gladys Marcela Avendaño-Sánchez. "Geochemical Characterization and Thermal Maturation of Cerrejón Formation: Implications for the Petroleum System in the Ranchería Sub-Basin, Colombia." Geosciences 10, no. 7 (July 4, 2020): 258. http://dx.doi.org/10.3390/geosciences10070258.

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The Upper Paleocene Cerrejón Formation is a great source of coal in Colombia. The northeastern part of the Ranchería Sub-Basin sees the most intense mining activity. As a consequence, all geological studies have been concentrated on this region. Consequently, neither the distribution of the Cerrejón Formation, nor the quality and quantity of organic matter in the rest of the sub-basin is clear. In this study, we analyzed new geochemical data from Rock–Eval pyrolysis analyses and vitrinite reflectance using core samples from the ANH-CAÑABOBA-1 and ANH-CARRETALITO-1 wells. Based on this information, it was possible to classify the geochemical characteristics of the Cerrejón Formation as a source rock, particularly in the central area of the sub-basin, which had not been extensively studied before. Additionally, based on the interpretation of seismic reflection data, the numerical burial history models were reconstructed using PetroMod software, in order to understand the evolution of the petroleum system in the sub-basin. The models were calibrated with the data of maximum pyrolysis temperature (Tmax), vitrinite reflectance (%Ro), and bottom hole temperature (BHT). We infer the potential times of the generation and expulsion of hydrocarbon from the source rock.

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Pierrel, Fabien, Oleh Khalimonchuk, Paul A. Cobine, Megan Bestwick, and Dennis R. Winge. "Coa2 Is an Assembly Factor for Yeast Cytochrome c Oxidase Biogenesis That Facilitates the Maturation of Cox1." Molecular and Cellular Biology 28, no. 16 (June 9, 2008): 4927–39. http://dx.doi.org/10.1128/mcb.00057-08.

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ABSTRACT The assembly of cytochrome c oxidase (CcO) in yeast mitochondria is dependent on a new assembly factor designated Coa2. Coa2 was identified from its ability to suppress the respiratory deficiency of coa1Δ and shy1Δ cells. Coa1 and Shy1 function at an early step in maturation of the Cox1 subunit of CcO. Coa2 functions downstream of the Mss51-Coa1 step in Cox1 maturation and likely concurrent with the Shy1-related heme a 3 insertion into Cox1. Coa2 interacts with Shy1. Cells lacking Coa2 show a rapid degradation of newly synthesized Cox1. Rapid Cox1 proteolysis also occurs in shy1Δ cells, suggesting that in the absence of Coa2 or Shy1, Cox1 forms an unstable conformer. Overexpression of Cox10 or Cox5a and Cox6 or attenuation of the proteolytic activity of the m-AAA protease partially restores respiration in coa2Δ cells. The matrix-localized Coa2 protein may aid in stabilizing an early Cox1 intermediate containing the nuclear subunits Cox5a and Cox6.

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45

Bearce, Bradford C., and Dharmalingam S. Pitchay. "Producing Blue and Pink Flowers on Hydrangea Using Coal Bottom Ash as a Media Component." HortScience 33, no. 3 (June 1998): 465b—465. http://dx.doi.org/10.21273/hortsci.33.3.465b.

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Rooted terminal tip cuttings of hydrangea (Hydrangea macrophylla Thunb. `Blaumeise Lace Cap') were transplanted into 10-cm azalea pots containing 1 peat: 1 vermiculite (by volume) into which CBA (sieved through 6-mm screen) had been mixed at 0%, 25%, or 50% on 18 Aug. 1996. They were then grown until bud maturation on 21Nov., precooled, and brought into the greenhouse for forcing on 9 Jan. 1997. The substrate pH levels were adjusted to 6.0–6.5 for pink flowers with dolomitic lime and with Al2(SO4)3 to a pH range of 5.0–5.5. Measurements were performed at anthesis on 19 Apr. There were no significant differences in fresh and dry weight and root quality index from 0% through 75% CBA media, but these parameters were reduced in 100% CBA for both blue- and pink-flowered plants. Plant heights and diameters were equal in 0% through 75% CBA and ranged from 16.33 to 17.56 cm and 17.33 to 18.06 cm, respectively, but were significantly reduced in 100% CBA for blue-flowered plants. Plant heights and diameters were equal in 0% through 100% CBA for pink-flowered plants and ranged from 21.0 to 24.0 and 19.3 to 23.5 cm, respectively. Diameters of blue inflorescences ranged from 95.9 to 104.9 cm, and these were equal on plants in 0% through 100% CBA. However, diameters of pink inflorescences ranged from 114.2–155.6 cm and were significantly reduced on plants in 25%, 50%, and 100% CBA.

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46

Dean, Mark T., and Nicholas Turner. "Conodont Colour Alteration Index (CAI) values for the Carboniferous of Scotland." Transactions of the Royal Society of Edinburgh: Earth Sciences 85, no. 3 (1994): 211–20. http://dx.doi.org/10.1017/s0263593300003606.

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AbstractConodont elements from Scottish Carboniferous rocks have been reviewed for Colour Alteration Index(CAI) data, and most values range between 1 and 1·5. Assuming a local average geothermal gradient similar to that of today, the observed and predicted CAI values generally fit well. Only a few of the samples analysed were influenced by local igneous intrusives. The CAI range shown lies within the immature (early dry gas) to mature (perhapsmid-oil window) stages of hydrocarbon generation, and this suggests that burial maturation (where CAI values are 1-5) could account for locally generated oil, where this occurred away from igneous intrusions. Alkali-dolerite and tholeiitic intrusives are, however, widespread in the Midland Valley of Scotland, and an understanding of their thermal effects has implications for both coal and petroleum exploration. The insensitivity of conodonts to low temperatures is noted, and the relevance, application and potential of various other palaeothermometers is discussed. Locally, the qualitative study of spore colour (SCI) appears useful.

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47

Hawkins, P. J., and P. M. Green. "EXPLORATION RESULTS, HYDROCARBON POTENTIAL AND FUTURE STRATEGIES FOR THE NORTHERN GALILEE BASIN." APPEA Journal 33, no. 1 (1993): 280. http://dx.doi.org/10.1071/aj92020.

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Exploration activity in the northern Galilee Basin has been sporadic and is still at an immature stage. Recent geological investigations by the Queensland Department of Resource Industries have brought about a better understanding of the geological setting and stratigraphic evolution of the basin. These investigations also identified key source and reservoir units, determined maturation trends and delineated areas with hydrocarbon potential. The geological results indicate that the Aramac Coal Measures and Betts Creek beds contain the most favourable source and reservoir rocks. Thermal modelling of vitrinite reflectance data suggests that various parts of the basin reached maturity for hydrocarbon generation at different times. Integration of the geological results and thermal modelling has enabled exploration concepts to be developed for the basin. Application of these concepts has highlighted areas along the western margin of the Koburra Trough and eastern Maneroo Platform, and areas adjacent to the Cork Fault and the Wetherby Structure in the Lovelle Depression that warrant further exploration.

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48

Liu, Yu, Yanming Zhu, Shimin Liu, and Chuanghui Zhang. "Evolution of Aromatic Clusters in Vitrinite-Rich Coal during Thermal Maturation by Using High-Resolution Transmission Electron Microscopy and Fourier Transform Infrared Measurements." Energy & Fuels 34, no. 9 (August 10, 2020): 10781–92. http://dx.doi.org/10.1021/acs.energyfuels.0c01891.

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49

Ragab Shalaby, Mohamed, Nurhazwana Jumat, Md Aminul Islam, and Stavros Kalaitzidis. "Source and Reservoir Characteristics of the Eocene Mangahewa Formation in Taranaki Basin, New Zealand: Their implications on petroleum system." Scientia Bruneiana 19, no. 1 (January 30, 2021): 34–77. http://dx.doi.org/10.46537/scibru.v19i1.113.

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The Middle to Late Eocene Mangahewa Formation in the Taranaki Basin has been evaluated for its petroleum system (source potential and reservoir qualities). The Mangahewa Formation is generally interpreted as an alternating marginal to shallow marine environment, with lithologies consisting of sandstone, siltstone, mudstone and bitumonius coal. The pyrolysis results show very good source rock generative potential with total organic carbon content of 0.8-90.02 wt. % and hydrogen index values in the range of 54- 491 mg HC/g TOC, with a predominance of oil- and/or gas-prone, mixed Type II-III kerogen. Organic petrographical data reveal that the humic nature of coals being rich in perhydrous vitrinite whereas shales are rich in alginite and bituminite desplaying frequent of migrabitumens. Biomarker analysis suggests predominantly terrigenous origin, whereas pyrolysis Tmax data (414–447°C) and other maturity indicators such as biomarkers and vitrinite reflectance indicates immature and mature samples. Petrographic analyses show that the occurrence of compaction and cementation is succeeded by leaching of feldspars and dissolution of calcite cement. The reservoir samples exhibit largely good reservoir quality with porosity being the dominant feature. The average porosity value is 15.7%, with 21.4% average water saturation. The source and reservoir units are part of a complete petroleum system of the Mangahewa Formation, with the overlying Turi Formation seal rock. The petroleum processes of maturation, generation, and migration which started since Lower Miocene (18.8 Ma) have been recorded in many stratigraphic traps within the Mangahewa Formation or other faulted structural traps due to migration. The generation process is expected to continue to the present day as the source continues to attain maturity while it does not yet reach the peak generation.

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50

Li, Y., R. Michels, L. Mansuy, S. Fleck, and P. Faure. "Comparison of pressurized liquid extraction with classical solvent extraction and microwave-assisted extraction–application to the investigation of the artificial maturation of Mahakam coal." Fuel 81, no. 6 (April 2002): 747–55. http://dx.doi.org/10.1016/s0016-2361(01)00192-2.

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