Journal articles: 'Surat Basin'

1

Yassi, Nabeel, and Afsha Kaba. "Seismic source comparison in Surat Basin, Queensland." ASEG Extended Abstracts 2013, no. 1 (December 2013): 1–4. http://dx.doi.org/10.1071/aseg2013ab198.

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2

Reilly, Mark, Suzanne Hurter, Zsolt Hamerli, Claudio L. de Andrade Vieira Filho, Andrew LaCroix, and Sebastian Gonzalez. "An integrated approach to the Surat Basin stratigraphy." APPEA Journal 59, no. 2 (2019): 940. http://dx.doi.org/10.1071/aj18073.

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The stratigraphy of the Surat Basin, Queensland, has historically been sub-divided by formation and unit nomenclature with a few attempts by other authors to apply sequence stratigraphy to existing formation boundaries. At a local- to field-scale, lithostratigraphy may be able to represent stratigraphy well, but at regional-scale, lithostratigraphic units are likely to be diachronous. To date, this lithology-driven framework does not accurately reflect time relationships in the sub-surface. An entirely new integrated methodological approach, involving well tied seismic data and sequence stratigraphic well-to-well correlations compared with published zircon age dates, has been applied to hundreds of deep wells and shallower coal seam gas wells. This method sub-divides the Surat Basin stratigraphy into defendable 2nd order to 3rd order sequence stratigraphic cycles and has required the use of an alpha-numeric sequence stratigraphic nomenclature to adequately and systematically label potential time equivalent surfaces basin-wide. Correlation of wells is the first step in building models of aquifers and coal seam gas fields for numerical simulation of fluid flow, which is necessary for responsible resource management. Lithostratigraphic correlations will overestimate the extent and hydraulic connectedness of the strata of interest. The result may be fluid flow models that do not represent a realistic pressure footprint of the flow. The present sequence stratigraphic method more accurately reflects the disconnectedness of sub-surface coals and sandstones (aquifers) on a field-to-field scale, adjacent field-scale, and basin-wide scale. It forms the basis for improved and more representative modelling of the sub-surface.

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Harris, Kathryn, Vair Pointon, and Ryan Morris. "The presence of natural methane in Great Artesian Basin aquifers of the Surat Basin." APPEA Journal 52, no. 2 (2012): 674. http://dx.doi.org/10.1071/aj11088.

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The Surat Basin portion of the Great Artesian Basin (GAB) in Queensland has long been known to contain natural gas from both conventional and CSG sources. Commercial gas extraction from conventional sources target the Evergreen and Precipice Formations, which are among the lowermost of the Surat Basin stratigraphic units; however, evidence exists of methane occurrences in waterbores, which in most cases, access aquifers much shallower than recognised conventional gas or CSG targets. Large-scale development of CSG in the Surat and southern Bowen basins has highlighted the presence of gas in aquifers overlying and underlying the coal measures. Potential issues associated with gas in waterbores include health and safety risks, and the difficulty of establishing baseline groundwater bore conditions against which potential CSG impacts can be compared. Australia Pacific LNG has been investigating the presence of gas in the aquifers across the basin. The program has involved the routine measurement of wellhead gas concentrations and analysis of dissolved gas in waterbores. Stable isotope analysis of the dissolved methane (δ13C-methane and δD-methane) has been undertaken to ‘fingerprint’ aquifer gasses to ascertain their provenance. More recently, δ13C-CO2 has been added to the suite of isotopes. Initial results confirm the presence of natural methane across the study area and in all of the GAB aquifers sampled. Isotopic analysis indicates a distinct difference in isotopic signatures between the methane from the coal measures and that of the overlying aquifers from which most groundwater is extracted.

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Woods, Megan, Rajendra P. Adhikari, Laurie Bonney, Andrew Harwood, Sophie Ross, Lea Coates, and Robyn Eversole. "Regional development and the Toowoomba Surat Basin Enterprise organization." Small Enterprise Research 25, no. 3 (September 2, 2018): 290–302. http://dx.doi.org/10.1080/13215906.2018.1522273.

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5

Garnett, A., S. Gonzalez, S. Guiton, and S. Hurter. "Preliminary Containment Evaluation in the Surat Basin, Queensland, Australia." Energy Procedia 37 (2013): 4910–18. http://dx.doi.org/10.1016/j.egypro.2013.06.402.

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Ryan, Damien, Andrew Hall, Leon Erriah, and Paul Wilson. "The Walloon coal seam gas play, Surat Basin, Queensland." APPEA Journal 52, no. 1 (2012): 273. http://dx.doi.org/10.1071/aj11020.

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Extensive drilling of the Walloon Subgroup for coal seam gas (CSG) during the last decade has revealed a world-class CSG play on the northern flank of the Surat Basin. Resources discovered in the Walloon Subgroup exceed 30 TCF; this gas now underpins four CSG-to-liquefied natural gas (LNG) projects. Results to date have revealed the highly heterogeneous nature of the Walloon Subgroup and its associated coal properties. The Walloon Subgroup is typically 350 m thick and contains an average of 30 m of net coal that is interbedded with a range of clay-rich, fluvio-lacustrine lithologies. The most prospective area of the play occurs down-dip and adjacent to the Walloon subcrop edge, where high permeability exists combined with a thick section of net pay. Coals in the Walloon Subgroup are low rank (0.35–0.65% Ro) with gas contents ranging between 1–15 m3/tonne (dry ash-free). Average coal ply thickness is 30 cm, making correlation and prediction of reservoir properties difficult. Reservoir properties—including permeability, gas content and saturation—differ as a result of compositional variability of the coal seams and also the tectonic history. Mapping of sparse 2D seismic data has highlighted the distribution of major structural features throughout the basin. Coal fracture permeability ranges from less than 0.1 mD to more than 2,000 mD, and mapping has identified areas where permeability appears to be enhanced on structures that have undergone mid Cretaceous–Eocene deformation.

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Papendick, Samuel L., Kajda R. Downs, Khang D. Vo, Stephanie K. Hamilton, Grant K. W. Dawson, Suzanne D. Golding, and Patrick C. Gilcrease. "Biogenic methane potential for Surat Basin, Queensland coal seams." International Journal of Coal Geology 88, no. 2-3 (November 2011): 123–34. http://dx.doi.org/10.1016/j.coal.2011.09.005.

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8

Babaahmadi, Abbas, Renate Sliwa, and Joan Esterle. "Post Jurassic shortening in the western Surat Basin relative to underlying basement depth and faulting." APPEA Journal 56, no. 2 (2016): 597. http://dx.doi.org/10.1071/aj15103.

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The Hutton-Wallumbilla (HWF), Merivale (MF), Kia Ora, and Injune faults are the major structures in the western Surat Basin, deforming Palaeozoic to Jurassic rock units. The authors present results from the interpretation of gridded gravity data and open-file seismic reflection data, which provide constraints on the geometry and kinematics of these faults. The interpretation of gravity data indicates that the HWF and MF are expressed by sharp lineaments in moderate to high-amplitude anomalies, indicating a deep-seated nature of the faults. The interpretation of seismic lines shows that the HWF and MF are northeast-dipping and east-dipping reverse blind faults, respectively. Some other faults also displaced and folded the rock units of the Bowen and Surat basins, such as the Kia Ora and Injune faults. The MF, Kia Ora, and the northern part of the HWF acted as normal faults during the early Permian and then have been inverted during the Late Permian–Triassic Hunter-Bowen Orogeny phases, especially during the early Late Triassic. The largest fault throws in the Bowen Basin successions are observed along the southern part of the HWF and its central splay, which are around 350 m and 480 m, respectively. The stratigraphic units of the Surat Basin above it have gently been folded over the major blind faults. The largest amount of shortening in the Surat Basin has taken place over the southern part of the HWF by 0.5%. The basement depth played an important role in the amount of contractional deformation in the Bowen and Surat basins. Where the basement is shallow, the amount of deformation along the faults in both the Bowen and Surat basins is higher.

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Dorling, M., R. Taylor, and S. Hearn. "Lower impact seismic reflection- trialling envirovibes in the Surat Basin." ASEG Extended Abstracts 2009, no. 1 (2009): 1. http://dx.doi.org/10.1071/aseg2009ab005.

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10

Levy, Mitchell, and Oliver Gaede. "Identification of Clay Minerals Within the Springbok Formation, Surat Basin." ASEG Extended Abstracts 2018, no. 1 (December 2018): 1–8. http://dx.doi.org/10.1071/aseg2018abp003.

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11

Rigby, S. M., and A. J. Kantsler. "MURILLA CREEK — AN UNTESTED STRATIGRAPHIC PLAY IN THE SURAT BASIN." APPEA Journal 27, no. 1 (1987): 230. http://dx.doi.org/10.1071/aj86019.

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In 1978 Shell farmed into Western Mining Corporation's (WMC) permit ATP-241P in the central Surat Basin. A major objective of the venture was to explore for Lower Jurassic stratigraphic traps in the Murilla Creek area on the western flank of the Mimosa Syncline.The Murilla Creek stratigraphic play comprises a series of sand-filled valleys incised into the base Jurassic unconformity surface, forming a dendritic drainage pattern which supplied sediment to the braided stream deposits of the Lower Precipice Sandstone to the east. At their western depositional limit these potential reservoirs are likely to be sealed vertically by a regionally extensive lacustrine shale, and laterally by siltstones and shales within the sub-cropping Middle Triassic Moolayember Formation. Oil charge may either be directly from underlying Triassic source rocks or indirectly from the Permian Blackwater and Back Creek Groups. Exploration of the Murilla Creek area involved the acquisition of 776 km of experimental, reconnaissance and infill seismic and one well (Coalbah 1) which enabled seismic calibration and delineation of the Lower Precipice Sandstone to its seismically resolvable limits.Seismic interpretation confirmed the potential for several stratigraphic traps in the Murilla Creek area. However trap geometries and seal constraints suggest that any stratigraphically trapped oil accumulation would be small (less than 3 MMBBL). Coupled with the considerable geological risks associated with the stratigraphic play, the low potential rewards rendered the play economically unattractive to Shell and WMC and the acreage was subsequently relinquished. However the Murilla Creek stratigraphic play remains untested and, in view of the potential for numerous small oil accumulations, may prove to be an attractive exploration target under more favourable economic circumstances.

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12

Wainman, Carmine, and Peter McCabe. "Revisions to the chronostratigraphic framework of the Upper Jurassic Walloon Coal Measures of the Surat Basin, Australia." APPEA Journal 59, no. 2 (2019): 965. http://dx.doi.org/10.1071/aj18067.

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The Upper Jurassic Walloon Coal Measures (WCM) in the Surat Basin host the largest coal seam gas (CSG) resource in Australia. Despite this, a poorly defined lithostratigraphic framework hinders the development of reservoir models and groundwater flow simulations. Correlations in the WCM are challenging, owing to the complex arrangement of facies over short distances and the absence of a reliable regional stratigraphic datum. To better correlate the strata, 26 tuff beds were dated using the U–Pb chemical abrasion thermal ionisation mass spectrometry methodology across the Surat Basin CSG fairway. This initially suggested that coal-bearing strata in the basin were diachronous. However, the acquisition of a new date from the Surat Basin has identified a five million year time gap between dated tuffs ~20 m apart. This suggests the presence of an unconformity and that there were two independent episodes of coal accumulation in the basin. Above the unconformity, there are incised valleys with a sedimentary infill that transitions from fluvial- to tidal-influenced facies, as indicated by dinoflagellate cysts and tidal sedimentary structures, including double mud drapes. The cause of the unconformity is likely to be tectonic, as eustatic sea-level was rising during the Kimmeridigian. The marine incursion into the basin is the consequence of a highstand of sea-level during the early Tithonian. The application of the new chronostratigraphic framework should elucidate the evolution of fluviolacustrine systems in the basin and aid in resource prediction. Further dating of tuffs in the basin could refine the stratigraphic framework.

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13

Kaushik, Pankaj R., Christopher E. Ndehedehe, Ryan M. Burrows, Mark R. Noll, and Mark J. Kennard. "Assessing Changes in Terrestrial Water Storage Components over the Great Artesian Basin Using Satellite Observations." Remote Sensing 13, no. 21 (November 6, 2021): 4458. http://dx.doi.org/10.3390/rs13214458.

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The influence of climate change and anthropogenic activities (e.g., water withdrawals) on groundwater basins has gained attention recently across the globe. However, the understanding of hydrological stores (e.g., groundwater storage) in one of the largest and deepest artesian basins, the Great Artesian Basin (GAB) is limited due to the poor distribution of groundwater monitoring bores. In this study, Gravity Recovery and Climate Experiment (GRACE) satellite and ancillary data from observations and models (soil moisture, rainfall, and evapotranspiration (ET)) were used to assess changes in terrestrial water storage and groundwater storage (GWS) variations across the GAB and its sub-basins (Carpentaria, Surat, Western Eromanga, and Central Eromanga). Results show that there is strong relationship of GWS variation with rainfall (r = 0.9) and ET (r = 0.9 to 1) in the Surat and some parts of the Carpentaria sub-basin in the GAB (2002–2017). Using multi-variate methods, we found that variation in GWS is primarily driven by rainfall in the Carpentaria sub-basin. While changes in rainfall account for much of the observed spatio-temporal distribution of water storage changes in Carpentaria and some parts of the Surat sub-basin (r = 0.90 at 0–2 months lag), the relationship of GWS with rainfall and ET in Central Eromanga sub-basin (r = 0.10–0.30 at more than 12 months lag) suggest the effects of human water extraction in the GAB.

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14

Beresford, Greg, and Randall Taylor. "Seismic source modelling and 3D survey parameter design, Surat Basin, Australia." ASEG Extended Abstracts 2004, no. 1 (December 2004): 1–5. http://dx.doi.org/10.1071/aseg2004ab011.

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15

Khorasani, Ganjavar Khavari. "Oil-prone coals of the Walloon Coal Measures, Surat Basin, Australia." Geological Society, London, Special Publications 32, no. 1 (1987): 303–10. http://dx.doi.org/10.1144/gsl.sp.1987.032.01.16.

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16

Garnett, A., S. Hurter, N. Marmin, P. Probst, S. Gonzalez, and S. Guiton. "Injectivity in the Surat Basin, Queensland, Australia: Likelihood and Uncertainty Evaluation." Energy Procedia 37 (2013): 3747–54. http://dx.doi.org/10.1016/j.egypro.2013.06.270.

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17

Morris, Ryan, and Marcus Horgan. "Aquifer injection for CSG water management in the Surat Basin, Queensland." APPEA Journal 52, no. 2 (2012): 676. http://dx.doi.org/10.1071/aj11090.

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Appropriate water management associated with CSG production is key to regulatory approval and public acceptance of CSG projects. Policy in Queensland makes injection of treated produced water the government's main and preferred option for CSG water management to ensure protection of the Great Artesian Basin as a groundwater resource. In 2010, Australia Pacific LNG started an extensive program of aquifer injection trials across its Surat and southern Bowen Basin CSG fields. The purpose of the trials is to assess the technical and economic feasibility of aquifer injection. The trial program comprises nine different injection targets across four locations and three aquifers. Target depths range from less than 100 m to about 1,500 m. A process of desktop study-exploration-testing has been followed. To date, Australia Pacific LNG has completed all exploration activities. These included about 1,200 m of coring, an extensive suite of geophysical logging and post processing, hydraulic testing and physical, geochemical and mineralogical analyses. This extended abstract describes the results of the exploration activities and the decisions made based on the acquired data. Comparisons are made between the different sites and aquifers. Results of the testing are discussed in the context of technical and economic feasibility of a large-scale injection scheme.

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18

Draper, J. J., and C. J. Boreham. "GEOLOGICAL CONTROLS ON EXPLOITABLE COAL SEAM GAS DISTRIBUTION IN QUEENSLAND." APPEA Journal 46, no. 1 (2006): 343. http://dx.doi.org/10.1071/aj05019.

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Methane is present in all coals, but a number of geological factors influence the potential economic concentration of gas. The key factors are (1) depositional environment, (2) tectonic and structural setting, (3) rank and gas generation, (4) gas content, (5) permeability, and (6) hydrogeology. Commercial coal seam gas production in Queensland has been entirely from the Permian coals of the Bowen Basin, but the Jurassic coals of the Surat and Clarence-Moreton basins are poised to deliver commercial gas volumes.Depositional environments range from fluvial to delta plain to paralic and marginal marine—coals in the Bowen Basin are laterally more continuous than those in the Surat and Clarence-Moreton basins. The tectonic and structural settings are important as they control the coal characteristics both in terms of deposition and burial history. The important coal seam gas seams were deposited in a foreland setting in the Bowen Basin and an intracratonic setting in the Surat and Clarence-Moreton basins. Both of these settings resulted in widespread coal deposition. The complex burial history of the Bowen Basin has resulted in a wide range of coal ranks and properties. Rank in the Bowen Basin coal seam gas fields varies from vitrinite reflectance of 0.55% to >1.1% Rv and from Rv 0.35-0.6% in the Surat and Clarence-Moreton basins in Queensland. High vitrinite coals provide optimal gas generation and cleat formation. The commercial gas fields and the prospective ones contain coals with >60% vitrinite.Gas generation in the Queensland basins is complex with isotopic studies indicating that biogenic gas, thermogenic gas and mixed gases are present. Biogenic processes occur at depths of up to a kilometre. Gas content is important, but lower gas contents can be economic if deliverability is good. Free gas is also present. Drilling and production techniques play an important role in making lower gas content coals viable. Since the Bowen and Surat basins are in a compressive regime, permeability becomes a defining parameter. Areas where the compression is offset by tensional forces provide the best chances for commercial coal seam gas production. Tensional setting such as anticline or structural hinges are important plays. Hydrodynamics control the production rate though water quality varies between the fields.

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19

Philp, R. P., and T. D. Gilbert. "A GEOCHEMICAL INVESTIGATION OF OILS AND SOURCE ROCKS FROM THE SURAT BASIN." APPEA Journal 26, no. 1 (1986): 172. http://dx.doi.org/10.1071/aj85017.

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A series of twelve oils and five source rocks and potential source rocks from the Surat Basin have been subjected to detailed geochemical analyses. Particular attention has been given to determining the distribution of various classes of biomarkers such as the steranes and triterpanes. The results from this study have shown that the Cabawin oil is derived from the Permian Back Creek Formation and has a high content of marine organic source material. The Triassic/Jurassic oils have a different source from the Cabawin oil and are dominated by land plant source material. Within the Triassic/Jurassic oils there are subtle variations in biomarker distributions suggesting that some oils may have small but additional amounts of different source materials. A number of Cretaceous and Jurassic potential source rocks (i.e. Walloon) have biomarker parameters clearly indicating levels of maturity at which oil generation is impossible.A number of the oils in this basin are extensively biodegraded. In particular biodegradation has been very heavy in the Riverslea/Yapunyah area. With the exception of Conloi oil, all the oils appear to have been exposed to similar levels of maturity. A biomarker migration parameter has provided some tentative evidence to suggest that, in general, oils in the southern part of the basin have migrated further than those in the northern part.In summary, the biomarker data from oils and source rocks of the Surat Basin have been used to provide a new insight into the origin of the Surat Basin oils and their post-formation history.

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20

Hamilton, D. S., C. B. Newton, M. Smyth, T. D. Gilbert, N. Russell, A. McMinn, and L. T. Etheridge. "THE PETROLEUM POTENTIAL OF THE GUNNED AH BASIN AND OVERLYING SURAT BASIN SEQUENCE, NEW SOUTH WALES." APPEA Journal 28, no. 1 (1988): 218. http://dx.doi.org/10.1071/aj87018.

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The Permo-Triassic Gunnedah Basin has good potential for the discovery of commercial petroleum. Gas shows have been reported from the Porcupine-Watermark, Black Jack and Digby Formations, and from the basal sandstone of the Purlawaugh Formation in the overlying Surat Basin sequence. Gas flowed on drill stem test from the Porcupine-Watermark Formation in the Wilga Park No. 1 discovery well although the find was sub-commercial. An oil show was observed in Lower Permian volcanics, and oil staining has been observed in the Pilliga Sandstone in several wells. The origin of oil staining in the Pilliga Sandstone is unknown, however, and may have been the result of diesel contamination during drilling operations.Structural style within the basin sequence is characterised by north-south and north-north-west/south- south-east trending anticlines which formed in response to periodic compressive and left lateral strike-slip movements along the main Hunter Mooki Thrust Fault. These anticlines are attractive exploration targets.Westerly-derived quartz-rich sandstones occur at several stratigraphic levels within the Black Jack Formation and within the upper Digby Formation. Sandstones of the western bed-load fluvial system (lower Black Jack Formation) are most prospective with thick sections (up to 8 m) giving permeabilities from several hundred to several thousand millidarcies. Marine reworked easterly-derived sandstones up to 12 m thick in the Black Jack and Watermark Formations have minor reservoir potential with permeabilities in the order of tens of millidarcies. All potential reservoirs within the sequence are considered to be adequately sealed. Regionally extensive shaly units deposited either by marine incursion or lacustrine inundation overlie most reservoir horizons; remaining reservoirs are capped by intraformational shales.Organic petrology and geochemistry indicate the best potential source rocks within the Gunnedah Basin are floodplain, lacustrine and shallow marine facies of the Purlawaugh, Napperby, Watermark, Maules Creek and Goonbri Formations. The shallow marine Arkarula Sandstone Member within the Black Jack Formation also has significant potential for oil generation. Vitrinite reflectance, liptinite auto-fluorescence and TAI values indicate Lower Permian sediments are marginally mature to mature for oil generation. Combining the data on source quality and quantity with thermal maturity, the Permian sediments - in particular the Watermark Formation - have the best potential for generating oil.

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21

Quinn, Matthew. "PESA year in review 2019 – development and production." APPEA Journal 60, no. 2 (2020): 371. http://dx.doi.org/10.1071/aj20010.

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Australia’s production has been steadily increasing since 2013 with the main contributors being the large liquefied natural gas (LNG) projects. The North Carnarvon Basin accounted for over half of Australian production in 2019, dominated by North West Shelf LNG, Gorgon, Wheatstone and Pluto. Just under a quarter of production was from the Bowen-Surat Basin, with the highest producing project being the Condabri, Talinga and Orana cluster of coal seam assets. The next most prolific basin was the Browse Basin at just over 10%, with Prelude and Ichthys, followed by the Gippsland at 7%. During the year, the Greater Enfield Project, in the North Carnarvon Basin, was brought onstream, which involved a 30-km tie-in of the Laverda and Cimatti fields to the Ngujima-Yin floating production, storage and offloading vessel at the Vincent Field via sub-sea pipelines. Also brought into production during 2019 was the Roma North and Project Atlas, Bowen-Surat Basin, coal bed methane projects. Gas from Roma North is exclusively contracted to the Gladstone LNG consortium while Project Atlas gas will be supplied to domestic customers.

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Bianchi, Valeria, Troy Smith, and Joan Esterle. "Stratigraphic forward model of Springbok Sandstone sedimentation controlled by dynamic topography." APPEA Journal 56, no. 2 (2016): 600. http://dx.doi.org/10.1071/aj15106.

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After a long history of conventional gas exploration, the eastern Surat Basin in Queensland has developed as an active regional exploration target for coal seam gas, hosting large gas reserves. Interest in understanding basin fill mechanisms for petroliferous basins has grown in response to their economic significance. The Surat Basin is characterised by sedimentary successions with geometric complexity due to difficulty in correlation of coal splitting, interburden facies, and overburden channel belts. The uncertainty increases away from well control, in particular towards the centre where the basin is sparsely drilled. The forward modelling in LECODE (landscape evolution climate ocean and dynamic earth) is an innovative geomorphic and stratigraphic forward modelling code capable of simulating surface evolution and clastic sedimentary processes in 3D through geological time. This numerical tool can be used to test geological scenarios and predict the associated grain size distribution and sediment dispersal as a high-resolution synthetic stratigraphic record. This work focuses on a stratigraphic forward model developed for the Springbok Formation (Late Jurassic) within the Surat Basin. The simulated stratigraphy matches with models proposed by companies, highlighting a depocenter trending northwest–southeast. The formation is divided in two units: lower Springbok, defined by a fining-upward sequence and characterised by high-accommodation space and overfilling processes; and upper Springbok, described as an overall fining-upward sequence, with locally coarsening-upward wedge (conformable with the Weald Sandstone). The 3D basin simulation forecasts high heterogeneity of depositional geometries and stratal termination in depocentral and marginal areas.

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Suto, Koya, and Jamie D. Doyle. "Seismic stratigraphy of the Late Permian Tinowon Formation, Surat Basin, Australia : new opportunities in a mature basin." ASEG Extended Abstracts 2001, no. 1 (December 2001): 1–4. http://dx.doi.org/10.1071/aseg2001ab137.

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24

Hamilton, S. K., J. S. Esterle, and R. Sliwa. "Stratigraphic and depositional framework of the Walloon Subgroup, eastern Surat Basin, Queensland." Australian Journal of Earth Sciences 61, no. 8 (October 10, 2014): 1061–80. http://dx.doi.org/10.1080/08120099.2014.960000.

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25

Smith, T., V. Bianchi, and F. A. Capitanio. "Subduction geometry controls on dynamic topography: implications for the Jurassic Surat Basin." Australian Journal of Earth Sciences 66, no. 3 (January 22, 2019): 367–77. http://dx.doi.org/10.1080/08120099.2018.1548376.

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26

Vink, Sue, Jim Underschultz, Sam Guiton, Juan Xu, and Vahab Honari. "Flow system of the Hutton sandstone in the northern Surat Basin, Australia." Hydrogeology Journal 28, no. 1 (January 6, 2020): 89–102. http://dx.doi.org/10.1007/s10040-019-02097-7.

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27

Dutta, Suryendu, Sanket Bhattacharya, Monalisa Mallick, Ashish Chandra Shukla, and Ulrich Mann. "Preserved lignin structures in early eocene Surat lignites, Cambay Basin, Western India." Journal of the Geological Society of India 79, no. 4 (April 2012): 345–52. http://dx.doi.org/10.1007/s12594-012-0055-6.

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28

Hoffmann, K. L., J. M. Totterdell, O. Dixon, G. A. Simpson, A. T. Brakel, A. T. Wells, and J. L. Mckellar. "Sequence stratigraphy of Jurassic strata in the lower Surat Basin succession, Queensland." Australian Journal of Earth Sciences 56, no. 3 (April 2009): 461–76. http://dx.doi.org/10.1080/08120090802698737.

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29

Cox, Randall, and Keith Phillipson. "Update of the Surat Underground Water Impact Report." APPEA Journal 56, no. 2 (2016): 547. http://dx.doi.org/10.1071/aj15053.

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The production of coal seam gas (CSG) involves the pumping of large volumes of groundwater to lower water pressure in coal seams. This has the potential to affect groundwater resources in the coal-bearing formations and in adjacent aquifers connected to the coal formations. The formations that are the target for CSG development in the Surat Basin in Queensland are part of the Great Artesian Basin multi-layered aquifer system and also underlie important alluvial water resources. There are multiple major CSG projects being developed in the area. Queensland has a regulatory framework to manage the impact of CSG water extraction on groundwater resources that includes cumulative management arrangements for areas of intensive development, where the groundwater impacts of multiple projects overlap. In a declared Cumulative Management Area, the Office of Groundwater Impact Assessment (OGIA) carries out a regional assessment of impacts of CSG water extraction, specifies an integrated regional water monitoring network, and assigns responsibilities to individual CSG companies to implement individual parts of the water monitoring network and other management actions. OGIA sets out the results in an underground water impact report (UWIR), which on approval becomes a statutory instrument. OGIA is an independent entity fully funded by a levy on petroleum tenure holders. The first Surat UWIR was approved in 2012. In early 2016, OGIA revised the Surat UWIR using a new regional groundwater flow model that incorporates updated knowledge of the groundwater flow system. The key content of the revised Surat UWIR is presented.

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Mai, P. S. Moore D. K. Hobday H., and Z. C. Sun. "COMPARISON OF SELECTED NON-MARINE PETROLEUM-BEARING BASINS IN AUSTRALIA AND CHINA." APPEA Journal 26, no. 1 (1986): 285. http://dx.doi.org/10.1071/aj85026.

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This paper summarises the geology and hydrocarbon potential of two Chinese and two Australian basins (Ordos, Northern Jiangsu, Eromanga, and Surat basins) in order to compare factors affecting the generation, migration, and entrapment of hydrocarbons. In all four basins, hydrocarbons are generated from nonmarine source rocks of lacustrine and fluvial-overbank origin. While the Chinese and Australian basins contain a similar range of sedimentary facies, from alluvial fan to lacustrine, the arrangement and relative thicknesses of these facies vary considerably as a result of different tectonic and palaeoclimatic settings.During the Triassic, the Ordos Basin was dominated by retroarc foredeep subsidence and the development of deep, fresh-water lakes with anoxic bottom waters. This non-bioturbated substrate, with Type I and II kerogen precursors, provided an excellent oil source for adjacent fan-delta, deltaic, and fluvial reservoirs, and for the unconformably overlying Jurassic fluvial valley-fill sandstone reservoirs.The Northern Jiangsu Basin was initiated by back-arc extension and underwent very rapid half-graben subsidence in the Eocene. Alluvial fan, shoreline, and fluvial facies aggraded in a relatively narrow zone along the active, faulted margin, and merged laterally into organic-rich shales which provided a local source for oil.By comparison, the Eromanga/Surat basins developed in response to gentle downwarp and reactivation of older structural trends. Reservoirs are largely restricted to craton-derived quartzose facies such as in the Hutton, Precipice, and Namur sandstones. There is probably a dual source for oil, from the underlying Permian (which may be the dominant source in the Surat Basin), and from shales deposited in shallow, partly oxygenated lakes and overbank facies of Jurassic age (important in the Eromanga, and possibly subordinate in the Surat Basin). Deep lacustrine facies, typical of the Chinese basins, did not develop. The greater abundance of oil in the Chinese nonmarine basins is explained in terms of tectonic and palaeoclimatic factors which yielded thicker and better quality source rocks, more rapid maturation, and a better juxtaposition of source rocks and good-quality reservoirs, thus providing short, highly efficient migration routes.

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Wake-Dyster, K. D., M. J. Sexton, D. W. Johnstone, C. Wright, and D. M. Finlayson. "Deep Seismic Profiling Across the Nebine Ridge, Surat Basin, Kumbarilla Ridge and Clarence Moreton Basin in Southern Queensland." Exploration Geophysics 18, no. 1-2 (March 1, 1987): 218–22. http://dx.doi.org/10.1071/eg987218.

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Lu, Xinyi, Stephen J. Harris, Rebecca E. Fisher, James L. France, Euan G. Nisbet, David Lowry, Thomas Röckmann, et al. "Isotopic signatures of major methane sources in the coal seam gas fields and adjacent agricultural districts, Queensland, Australia." Atmospheric Chemistry and Physics 21, no. 13 (July 14, 2021): 10527–55. http://dx.doi.org/10.5194/acp-21-10527-2021.

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Abstract. In regions where there are multiple sources of methane (CH4) in close proximity, it can be difficult to apportion the CH4 measured in the atmosphere to the appropriate sources. In the Surat Basin, Queensland, Australia, coal seam gas (CSG) developments are surrounded by cattle feedlots, grazing cattle, piggeries, coal mines, urban centres and natural sources of CH4. The characterization of carbon (δ13C) and hydrogen (δD) stable isotopic composition of CH4 can help distinguish between specific emitters of CH4. However, in Australia there is a paucity of data on the various isotopic signatures of the different source types. This research examines whether dual isotopic signatures of CH4 can be used to distinguish between sources of CH4 in the Surat Basin. We also highlight the benefits of sampling at nighttime. During two campaigns in 2018 and 2019, a mobile CH4 monitoring system was used to detect CH4 plumes. Sixteen plumes immediately downwind from known CH4 sources (or individual facilities) were sampled and analysed for their CH4 mole fraction and δ13CCH4 and δDCH4 signatures. The isotopic signatures of the CH4 sources were determined using the Keeling plot method. These new source signatures were then compared to values documented in reports and peer-reviewed journal articles. In the Surat Basin, CSG sources have δ13CCH4 signatures between −55.6 ‰ and −50.9 ‰ and δDCH4 signatures between −207.1 ‰ and −193.8 ‰. Emissions from an open-cut coal mine have δ13CCH4 and δDCH4 signatures of -60.0±0.6 ‰ and -209.7±1.8 ‰ respectively. Emissions from two ground seeps (abandoned coal exploration wells) have δ13CCH4 signatures of -59.9±0.3 ‰ and -60.5±0.2 ‰ and δDCH4 signatures of -185.0±3.1 ‰ and -190.2±1.4 ‰. A river seep had a δ13CCH4 signature of -61.2±1.4 ‰ and a δDCH4 signature of -225.1±2.9 ‰. Three dominant agricultural sources were analysed. The δ13CCH4 and δDCH4 signatures of a cattle feedlot are -62.9±1.3 ‰ and -310.5±4.6 ‰ respectively, grazing (pasture) cattle have δ13CCH4 and δDCH4 signatures of -59.7±1.0 ‰ and -290.5±3.1 ‰ respectively, and a piggery sampled had δ13CCH4 and δDCH4 signatures of -47.6±0.2 ‰ and -300.1±2.6 ‰ respectively, which reflects emissions from animal waste. An export abattoir (meat works and processing) had δ13CCH4 and δDCH4 signatures of -44.5±0.2 ‰ and -314.6±1.8 ‰ respectively. A plume from a wastewater treatment plant had δ13CCH4 and δDCH4 signatures of -47.6±0.2 ‰ and -177.3±2.3 ‰ respectively. In the Surat Basin, source attribution is possible when both δ13CCH4 and δDCH4 are measured for the key categories of CSG, cattle, waste from feedlots and piggeries, and water treatment plants. Under most field situations using δ13CCH4 alone will not enable clear source attribution. It is common in the Surat Basin for CSG and feedlot facilities to be co-located. Measurement of both δ13CCH4 and δDCH4 will assist in source apportionment where the plumes from two such sources are mixed.

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Farquhar, S. M., G. K. W. Dawson, J. S. Esterle, and S. D. Golding. "Mineralogical characterisation of a potential reservoir system for CO2sequestration in the Surat Basin." Australian Journal of Earth Sciences 60, no. 1 (February 2013): 91–110. http://dx.doi.org/10.1080/08120099.2012.752406.

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34

Shields, D., and J. Esterle. "Regional insights into the sedimentary organisation of the Walloon Subgroup, Surat Basin, Queensland." Australian Journal of Earth Sciences 62, no. 8 (November 17, 2015): 949–67. http://dx.doi.org/10.1080/08120099.2015.1127287.

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35

La Croix, Andrew D., Jianhua He, Valeria Bianchi, Jiahao Wang, Sebastian Gonzalez, and Jim R. Undershultz. "Early Jurassic palaeoenvironments in the Surat Basin, Australia – marine incursion into eastern Gondwana." Sedimentology 67, no. 1 (November 21, 2019): 457–85. http://dx.doi.org/10.1111/sed.12649.

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36

Gaede, Oliver, Florian Wellmann, Thomas Flottmann, and Klaus Regenauer-Lieb. "Information Theory Based Probabilistic Machine Learning And Wireline Inversion: Surat Basin Case Study." ASEG Extended Abstracts 2019, no. 1 (November 11, 2019): 1–4. http://dx.doi.org/10.1080/22020586.2019.12073234.

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37

Phillipson, Keith. "Prediction of groundwater impacts from coal seam gas extraction in the Surat Basin." APPEA Journal 59, no. 2 (2019): 931. http://dx.doi.org/10.1071/aj18079.

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The Queensland regulatory framework recognises that the impacts of groundwater extraction activities can overlap in areas of concentrated development. Such areas of overlapping impacts can be declared ‘cumulative management areas’ (CMAs). When a CMA is established, the Office of Groundwater Impact Assessment (OGIA) becomes responsible for carrying out a cumulative impact assessment and preparing an Underground Water Impact Report (UWIR). The Surat CMA was declared in March 2011, and since this time, two iterations of the UWIR have been published in 2012 and 2016, underpinned by a gradually evolving regional groundwater flow model. This case study presentation will examine a number novel features of the regional groundwater flow model, resulting from OGIA’s ongoing research and development program, including the development of an adapted version of the MODFLOW-USG groundwater flow modelling code and approximation of coal desaturation and dual-phase flow effects using a modified van Genuchten function. The presentation will also look at the simulation of CSG extraction using a ‘descending drain’ methodology that recognises the gas-filled nature of CSG wells and generating up-scaled properties of highly heterogenous sedimentary material by first generating stochastic realisations of fragments of these layers, and then using ‘numerical permeameters’ to determine both the expected value and stochasticity of these properties, at the regional scale.

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38

Hamilton, S. K., J. S. Esterle, and S. D. Golding. "Geological interpretation of gas content trends, Walloon Subgroup, eastern Surat Basin, Queensland, Australia." International Journal of Coal Geology 101 (November 2012): 21–35. http://dx.doi.org/10.1016/j.coal.2012.07.001.

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39

Hawlader, H. M. "Diagenesis and reservoir potential of volcanogenic sandstones—Cretaceous of the Surat Basin, Australia." Sedimentary Geology 66, no. 3-4 (March 1990): 181–95. http://dx.doi.org/10.1016/0037-0738(90)90059-3.

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40

Korsch, J., C. J. Boreham, J. M. Totterdell, R. D. Shaw, and M. G. Nicoll. "DEVELOPMENT AND PETROLEUM RESOURCE EVALUATION OF THE BOWEN, GUNNEDAH AND SURAT BASINS, EASTERN AUSTRALIA." APPEA Journal 38, no. 1 (1998): 199. http://dx.doi.org/10.1071/aj97011.

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The Early Permian to Middle Triassic Bowen and Gunnedah basins and the Early Jurassic to Early Cretaceous Surat Basin in eastern Australia developed in response to a series of interplate and intraplate tectonic events located to the east of the basin system. The initial event was extensional and stretched the continental crust to form a significant Early Permian East Australian Rift System. The most important of the rift-related features are a series of half graben that form the Denison Trough, now the site of several commercial gas fields. Several contractional events from the mid-Permian to the Middle Triassic are associated with the development of a foreland fold and thrust belt in the New England Orogen. This caused a foreland loading phase of subsidence in the Bowen and Gunnedah basins. Thick coal measures deposited towards the end of the Permian are the most important hydrocarbon source rocks in these basins. The development of the Surat Basin marked a major change in the subsidence and sedimentation patterns. It was only towards the end of this subsidence that sufficient burial was achieved to put the source rocks over much of the basin into the oil window. Based on an evaluation of the undiscovered hydrocarbon resources for the Bowen and Surat basins in southern Queensland, our estimates of the yields of hydrocarbons suggest that significant volumes of hydrocarbons have been produced in the basins. The bulk of the hydrocarbons were generated after 140 Ma and most of the generation occurred in the late Early Cretaceous. Because the estimated volume of the hydrocarbons generated far exceeds the volume of discovered hydrocarbons, preservation of accumulations may be the main risk factor. The yield analysis, by demonstrating the potentially large quantities of hydrocarbons available, should act as a stimulus to exploration initiatives, particularly in the search for stratigraphic traps.

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Flook, Steven, Jon Fawcett, Randall Cox, Sanjeev Pandey, Gerhard Schöning, Jit Khor, Dhananjay Singh, Axel Suckow, and Matthias Raiber. "A multidisciplinary approach to the hydrological conceptualisation of springs in the Surat Basin of the Great Artesian Basin (Australia)." Hydrogeology Journal 28, no. 1 (January 21, 2020): 219–36. http://dx.doi.org/10.1007/s10040-019-02099-5.

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42

de Andrade Vieira Filho, Claudio L., Mark Reilly, Suzanne Hurter, and Zsolt Hamerli. "Integration of biostratigraphy into a sequence stratigraphic framework for the Surat Basin, eastern Australia." APPEA Journal 59, no. 2 (2019): 863. http://dx.doi.org/10.1071/aj18071.

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A new sequence stratigraphic framework (SSF) for the Early–Late Jurassic Surat Basin, eastern Australia, is evolving. A second and third order framework based upon an integrated methodology of well-to-well correlations supported by well tied seismic data is being developed. The integration of an additional dataset (palynology) to test for regionally consistent sequence stratigraphic well correlations offers an improvement in defining sequence boundaries related to the geological timescale. The palynological data from 33 wells covering the north-east Surat Basin were extracted from the Queensland Digital Exploration (QDEX) open-file reports, some of which date back to the 1960s. These data were correlated and superposed on the SSF for age comparison. The dataset used in this study represents only a subset of all existing palynology information, as not all data are captured in QDEX. However, the palynology data in this exploratory study generally fits and supports the new SSF with only one exception, the reason for which is not understood at this stage. We recommend expanding this study to include more data because palynology can support stratigraphic interpretation, especially in wells that do not intercept, or have log data across, regional datums.

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Young, Stuart R., Gerard F. C. Norton, and Ken Jun Foo. "Coal-Seam-Gas Reservoir Surveillance—Extracting Value From Suspended Coreholes, Surat Basin, Queensland, Australia." SPE Production & Operations 29, no. 02 (May 1, 2014): 088–96. http://dx.doi.org/10.2118/167050-pa.

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Gaede, Oliver, and Mitchell Levy. "Targeting Core Sampling with Machine Learning: Case Study from the Springbok Sandstone, Surat Basin." ASEG Extended Abstracts 2018, no. 1 (December 2018): 1–7. http://dx.doi.org/10.1071/aseg2018abm2_1c.

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La Croix, Andrew D., Valeria Bianchi, Mark Reilly, Joan Esterle, Jiahao Wang, Sebastian Gonzalez, and Jeff Copley. "The stratigraphic significance of paralic deposits in the Precipice–Evergreen succession, Surat Basin, Queensland." ASEG Extended Abstracts 2018, no. 1 (December 2018): 1–7. http://dx.doi.org/10.1071/aseg2018abm3_3c.

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Martin, M., M. Wakefield, V. Bianchi, J. Esterle, and F. Zhou. "Evidence for marine influence in the Lower Jurassic Precipice Sandstone, Surat Basin, eastern Australia." Australian Journal of Earth Sciences 65, no. 1 (December 11, 2017): 75–91. http://dx.doi.org/10.1080/08120099.2018.1402821.

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47

Ravestein, Johannes J., Cedric M. Griffiths, Chris P. Dyt, and Karsten Michael. "Multi-scale stratigraphic forward modelling of the Surat Basin for geological storage of CO2." Terra Nova 27, no. 5 (June 29, 2015): 346–55. http://dx.doi.org/10.1111/ter.12166.

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48

Gaede, Oliver, Mitchell Levy, David Murphy, Les Jenkinson, and Thomas Flottmann. "Well-log-constrained porosity and permeability distribution in the Springbok Sandstone, Surat Basin, Australia." Hydrogeology Journal 28, no. 1 (January 8, 2020): 103–24. http://dx.doi.org/10.1007/s10040-019-02086-w.

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49

Salehy, M. R. "Determination of rank and petrographic composition of Jurassic coals from eastern Surat Basin, Australia." International Journal of Coal Geology 6, no. 2 (July 1986): 149–62. http://dx.doi.org/10.1016/0166-5162(86)90018-2.

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50

Korsch, R. J., and J. M. Totterdell. "Subsidence history and basin phases of the Bowen, Gunnedah and Surat Basins, eastern Australia." Australian Journal of Earth Sciences 56, no. 3 (April 2009): 335–53. http://dx.doi.org/10.1080/08120090802698687.

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Journal articles on the topic 'Surat Basin'

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