Relevant bibliographies by topics / Beetaloo Basin

Academic literature on the topic 'Beetaloo Basin'

Author: Grafiati
Published: 10 December 2022
Last updated: 28 January 2023

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Journal articles on the topic "Beetaloo Basin"

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Frery, Emanuelle, Conor Byrne, Russell Crosbie, Alec Deslandes, Tim Evans, Christoph Gerber, Cameron Huddlestone-Holmes, et al. "Fault-Related Fluid Flow Implications for Unconventional Hydrocarbon Development, Beetaloo Sub-Basin (Northern Territory, Australia)." Geosciences 12, no. 1 (January 12, 2022): 37. http://dx.doi.org/10.3390/geosciences12010037.

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This study assesses potential geological connections between the unconventional petroleum plays in the Beetaloo Sub-basin, regional aquifers in overlying basins, and the near surface water assets in the Beetaloo Sub-basin Northern Territory, Australia. To do so, we built an innovative multi-disciplinary toolbox including multi-physics and multi-depth imaging of the geological formations, as well as the study of potentially active tectonic surface features, which we combined with measurement of the helium content in water sampled in the aquifer systems and a comparative analysis of the surface drainage network and fault lineaments orientation. Structures, as well as potential natural active and paleo-fluid or gas leakage pathways, were imaged with a reprocessing and interpretation of existing and newly acquired Beetaloo seismic reflection 2D profiles and magnetic datasets to determine potential connections and paleo-leakages. North to north-northwest trending strike slip faults, which have been reactivated in recent geological history, are controlling the deposition at the edges of the Beetaloo Sub-basin. There are two spring complexes associated with this system, the Hot Spring Valley at the northern edge of the eastern Beetaloo Sub-basin and the Mataranka Springs 10 km north of the western sub-basin. Significant rectangular stream diversions in the Hot Spring Valley also indicates current or recently active tectonics. This suggests that those deep-rooted fault systems are likely to locally connect the shallow unconfined aquifer with a deeper gas or fluid source component, possibly without connection with the Beetaloo unconventional prospective plays. However, the origin and flux of this deeper source is unknown and needs to be further investigated to assess if deep circulation is happening through the identified stratigraphic connections. Few north-west trending post-Cambrian fault segments have been interpreted in prospective zones for dry gas plays of the Velkerri Formation. The segments located in the northern part of the eastern Beetaloo Sub-basin do not show any evidence of modern leakages. The segments located around Elliot, in the south of the eastern Beetaloo Sub-basin, as well as low-quality seismic imaging of potential faults in the central part of the western sub-basin, could have been recently reactivated. They could act as open pathways of fluid and gas leakage, sourced from the unconventional plays, deeper formations of the Beetaloo Sub-basin or even much deeper origin, excluding the mantle on the basis of low 3He/4He ratios. In those areas, the data are sparse and of poor quality; further field work is necessary to assess whether such pathways are currently active.
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Côté, Alexander, Brenton Richards, Carl Altmann, Elizabeth Baruch, and David Close. "Australia's premier shale basin: five plays, 1 000 000 000 years in the making." APPEA Journal 58, no. 2 (2018): 799. http://dx.doi.org/10.1071/aj17040.

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The successful fracture stimulation and production test of the Amungee NW-1H well placed the Velkerri Shale play and the Beetaloo Sub-basin on Australia’s energy radar. The Velkerri Shale dry gas play is currently Australia’s most promising shale gas prospect; however, it is not the only prospect in the Beetaloo Sub-basin. Four additional potential plays have been identified, each with their own specific risk profile and relative benefits. These are the Velkerri Shale liquids rich gas play, the Kyalla Shale and hybrid liquids rich gas plays, and the Hayfield Sandstone oil/condensate play. Appraising each of these opportunities requires special attention to ensure efficient and appropriate deployment of capital. A framework approach allows for the high-level assessment and comparison of each of the discussed opportunities within the Beetaloo Sub-basin portfolio.
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Cockerill, Ian. "Australian exploration review 2020." APPEA Journal 61, no. 2 (2021): 331. http://dx.doi.org/10.1071/aj21006.

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Australian exploration battled on through the challenging headwinds of 2020 and surprisingly, 2020 saw an increase in exploration drilling on 2019 activity. Twenty-five exploration wells were drilled in 2020 versus 20 exploration wells drilled in 2019. Eight discoveries were made during the year, with the most significant being the Enterprise discovery in the Otway Basin. 2020 also saw a return to exploration drilling in the Beetaloo Sub-basin unconventional plays. Appraisal drilling was dominated by Cooper-Eromanga Basin and coal seam gas activity. There were no offshore appraisal wells in 2020. The exploration farm-in deals of note were Santos taking additional equity from Armour in their South Nicholson Basin unconventional project and Origin taking additional equity from Falcon in their Beetaloo Sub-basin unconventional project. Origin also farmed into the Canning Basin position of Buru Energy and Rey Resources. Australia is set for an exciting year of exploration ahead with a return to exploration drilling in the Bedout Sub-basin, further exploration drilling in the North Perth Basin and a continuation of drilling and testing of the unconventional plays in the Beetaloo Sub-basin.
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Granger, Dale. "The Empire Strikes Back with Spectacular Results in the Beetaloo." PESA News, no. 164 (March 23, 2022): 22–26. http://dx.doi.org/10.36404/aglz3960.

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Jarrett, Amber J. M., Tim J. Munson, Ben Williams, Adam H. E. Bailey, and Tehani Palu. "Petroleum supersystems in the greater McArthur Basin, Northern Territory, Australia: prospectivity of the world’s oldest stacked systems with emphasis on the McArthur Supersystem." APPEA Journal 62, no. 1 (May 13, 2022): 245–62. http://dx.doi.org/10.1071/aj21018.

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This study assesses the prospectivity of the world’s oldest known stacked petroleum systems from the Proterozoic greater McArthur Basin (Northern Territory, Australia), which has immense potential to host both conventional natural gas and oil, in addition to shale-gas accumulations. The Mesoproterozoic succession of the Beetaloo Sub-basin and surrounding region hosts the Territory’s premier shale-gas play and is at an advanced stage of exploration for shale hydrocarbon plays. However, there is also potential for natural gas in older sedimentary packages, with flows and shows reported in underlying Paleoproterozoic successions. At the continent-scale, four regional petroleum supersystems are identified and described in order to provide a platform for consistent nomenclature at the sedimentary package and group level; in ascending stratigraphic order; these are the Paleoproterozoic Redbank and McArthur supersystems, the Paleoproterozoic–Mesoproterozoic Lawn Supersystem, and the Mesoproterozoic Beetaloo Supersystem. The Redbank and Lawn supersystems are newly named and defined, and the Beetaloo Supersystem is renamed from the former Urapungan Supersystem. Eight possible conventional natural gas plays and six shale-gas plays are documented within the McArthur Supersystem, which incorporates Glyde Package successions of the McArthur Basin and the Birrindudu Basin. Petroleum play concepts are also described from this supersystem to assist with assessing the potential for gas resources. A better understanding of the petroleum systems of the greater McArthur Basin is critical to the targeting of areas for geoscience data acquisition in order to facilitate the reduction of exploration search space; and it enables a more rigorous assessment of the potential for conventional and unconventional hydrocarbon resources at local (play) and regional scales.
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Lanigan, Kevin, Shane Hibbird, Sandy Menpes, and John Torkington. "PETROLEUM EXPLORATION IN THE PROTEROZOIC BEETALOO SUB-BASIN, NORTHERN TERRITORY." APPEA Journal 34, no. 1 (1994): 674. http://dx.doi.org/10.1071/aj93050.

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Exploration over Roper Group outcrop in the McArthur Basin prompted Pacific Oil & Gas to investigate the petroleum potential of the Beetaloo Sub-basin, a 15 000 km2 Proterozoic depression concealed beneath Phanerozoic cover. Since 1989 drilling and seismic has identified a broadly flat-lying sequence with uplifted, eroded margins. A 3 500 m composite Proterozoic section consisting of three sandstone-to-mudstone sequences has been drilled. The lower two sequences comprise conformable units of the Mesoproterozoic upper Roper Group and unconformably overlying them is a previously unknown sequence comprising the informally labelled 'Jamison Sandstone' and 'Hayfield Mudstone', probably of Neoproterozoic age.Organic-rich intervals in the Roper Group mudstones range one to three per cent TOC in the Kyalla Member, and two to seven per cent TOC in the 'Middle' Velkerri Formation. Across most of the sub-basin the oil window lies within the Kyalla Member around 900–1350 m, while the 'Middle' Velkerri Formation is around 2 500 m and well into overmaturity, but may still have potential for gas. Potential reservoirs in the Bessie Creek, Moroak and 'Jamison' Sandstones, and in sandy units within the mudstones, are compromised by diagenesis, but porosities of up to 20 per cent and permeabilities of tens and rarely hundreds of millidarcies have been measured. Encouraging shows were observed in many of these intervals, and small quantities of oil and gas have been recovered in drill stem tests. With only a few targets drilled to date, this frontier area requires more exploration before its hydrocarbon potential can be adequately assessed.
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Huddlestone-Holmes, Cameron R., Kate Holland, and Luk J. M. Peeters. "Geological and Bioregional Assessments: a tale of two basins." APPEA Journal 61, no. 2 (2021): 491. http://dx.doi.org/10.1071/aj20036.

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The Australian Government’s $35.4 million Geological and Bioregional Assessment (GBA) Program is assessing the potential impacts of shale, tight and deep coal gas development on water and the environment in the Beetaloo, Isa and Cooper GBA regions. This paper compares the outcomes of impact assessments for the Beetaloo and Cooper GBA regions, highlighting the role that local geology, hydrogeology, ecology and regulatory regimes play when assessing potential impacts of unconventional gas development. Unconventional gas development activities between basins are broadly consistent, involving drilling, stimulation of the reservoir (typically through hydraulic fracturing), production and processing of hydrocarbons, export to market and decommissioning and rehabilitation. The characteristics of these activities and their potential impacts are strongly influenced by local factors including the geology, environment, industry practices and regulatory regimes. While subsurface impacts associated with hydraulic fracturing and well integrity are considered unlikely in both regions, regional geology means there is greater stratigraphic separation between target resources and overlying aquifers in the Beetaloo Sub-basin than in the Cooper Basin. Local ecological conditions and species influence the nature of potential impacts on protected matters in the two basins, which are mostly associated with surface disturbance and spills or accidental release of fluids. A key similarity between the two regions is the broadly consistent regulation and management of potential impacts in the two basins. Preliminary results of the causal network analysis indicate that mitigation measures are available for all pathways in which unconventional gas resource development activities may have the potential to impact on endpoints.
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Close, David, Alexander Côté, Elizabeth Baruch, Carl Altmann, Faiz Mohinudeen, Brenton Richards, Rachael Ilett, Ross Evans, and Stephanie Stonier. "Exploring the Beetaloo: will Australia's first viable shale play be sourced by billion year old gas?" APPEA Journal 57, no. 2 (2017): 716. http://dx.doi.org/10.1071/aj16054.

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Origin Energy completed exploration campaigns in 2015 and 2016 in the Beetaloo Sub-basin of the Greater McArthur Basin in the Northern Territory, drilling three vertical wells and one horizontal well. These wells have provided a wealth of technical data to assist in the characterisation of the primary source rock reservoirs or ‘shale gas’ plays in the Basin – the Velkerri Formation Play and the Kyalla Formation Play. In this paper we demonstrate the presence of thick, gas saturated and over-pressured source rocks across the sub-basin. In addition to the drilling campaign, the multi-stage hydraulic fracture stimulation of the Amungee NW-1H horizontal well was completed in 2016 – this operation was unique as it represents the first horizontal stimulation operation in the Beetaloo Sub-basin and the longest ‘plug and perf’ type horizontal completion in Australia. Data from the extended production test of the Amungee NW-1H are critical from a technical and, potentially, economic and political perspective. In addition to the technical work program, Origin has undertaken preliminary environmental baseline studies and substantial stakeholder engagement. Ensuring environmental baseline data are available is key to demonstrating that onshore gas developments can be undertaken without adverse environmental outcomes, and also for gaining social acceptance. However, data and facts alone are not sufficient to build community confidence. Origin has engaged extensively with pastoralists, local communities and Traditional Owners to build direct relationships and partnerships that encourage acceptance of the gas industry’s ability to coexist and deliver mutual benefits to the businesses and communities of the Barkly region and the Northern Territory more broadly.
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Markov, Jelena, Claudio Delle Piane, Ernest Swierczek, Clive Foss, and Mohinudeen Faiz. "Structural interpretation of the Beetaloo Sub-basin, NT from nonseismic geophysical data." APPEA Journal 61, no. 2 (2021): 679. http://dx.doi.org/10.1071/aj20194.

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The Beetaloo Sub-basin is known for its vast unconventional hydrocarbon resources even though it is relatively underexplored. There is reasonably good coverage of 2D seismic within the sub-basin which is used as the basis for most structural interpretations. However, seismic quality varies, and it is occasionally deteriorated by the presence of basalts from the Kalkarindji suite and the karstic nature of the Gum Ridge formation. Aeromagnetic data, constrained by petrophysical logs are used, to map faults in the basalts of the Kalkarindji suite and their lateral extent to the South and the East of the sub-basin. The same structural elements are identified in the full tensor gravity gradiometry data. The top of this unit is observed in the electrical conductivity profiles, derived from Tempest data, in the NW part of the eastern sub-basin.
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Robinson, David, Merrie-Ellen Gunning, Tim Evans, Lisa Hall, Baskaran Sundaram, Anthony Swirepik, Andrew Stacey, Rodney Dann, and Kate Holland. "Geological and bioregional assessments – enabling future tight, shale and deep coal gas development – Cooper Basin case study." APPEA Journal 59, no. 2 (2019): 946. http://dx.doi.org/10.1071/aj18165.

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The Australian Government’s Geological and Bioregional Assessment (GBA) Program is a series of independent scientific studies conducted by Geoscience Australia and CSIRO, supported by the Bureau of Meteorology and managed by the Department of the Environment and Energy. These studies focus on the Cooper, Isa and Beetaloo GBA regions, all of which include basins which are prospective, but under-explored, for shale, tight and/or deep coal gas. The GBA Program seeks to expedite development in order to bring new gas resources to the east coast gas market within the next 5–10 years through increased understanding of the potential environmental impacts posed by gas development and increasing the efficiency of assessment, monitoring and ongoing regulation, including improved data capture and reporting. This multi-agency program addresses the potential environmental impacts of gas development through geological and environmental baseline assessments and identification of major information gaps (Stage 2), followed by an analysis of the potential impacts on assets, including groundwater, surface water, environmental and cultural assets as well as Commonwealth and State matters of environmental significance (Stage 3). This paper will discuss how integrated conceptual models of the geology and hydrogeology of selected unconventional petroleum resources can be utilised by industry, regulators and other stakeholders. By establishing a baseline assessment for the Cooper Basin, which includes an integrated shale, tight and deep coal prospectivity and groundwater study, future development scenarios can be envisaged and the potential impact on groundwater and other resources contemplated. Similar baseline assessments and conceptual models are being developed for the Isa and Beetaloo GBA regions.
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Dissertations / Theses on the topic "Beetaloo Basin"

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Capogreco, N. "Provenance and thermal history of the Beetaloo Basin using illite crystallinity and zircon geochronology and trace element data." Thesis, 2017. http://hdl.handle.net/2440/126541.

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The Beetaloo Basin of the ‘greater McArthur Basin’, is a 15,000km2 Palaeoproterozoic depocenter which hosts shallow water, dominantly marine, clastic sedimentary rocks and is a large hydrocarbon reserve. Here I present LA-ICP-MS detrital zircon U-Pb age data, Rare Earth Elemental zircon and illite crystallinity XRD results and compare with existing studies to explore the variation in provenance throughout the basin and to better understand its temperature history as much of the basins’ history is still unknown. Nine sandstone and seventeen shale core samples were analysed. New constraints were placed on the depositional age for the Corcoran Formation to between 1390 ± 27 Ma and 1324 ± 4 Ma. The Velkerri Formation, Moroak Sandstone and Kyalla Formation of the Maiwok Sub-group all largely supported the results of previous studies yielding comparable maximum depositional ages. Zircon phosphorous concentrations revealed a largely I-type granitic source rock indicating the granites were formed in arc related settings. Detrital zircon age data revealed possible origins of sediments showing that the Corcoran Formation has a major source of ca. 1600 Ma zircons which are not unlike rocks from Eastern Queensland orogens. The Velkerri Formations’ main age peak falls at ca. 1765 Ma which shows a change to older detrital source rocks with more similarities to the Arunta and Kathleen and Western Orogenies. Moving up-section to the Moroak Sandstone and Kyalla Formations, samples shift to younger ca. 1560 Ma peak ages at the base of the Moroak followed by a gradual increase in age with younger sequences where a maximum peak age of ca. 1795 Ma is found in the mid Kyalla Formation. This gradual increase shows a gradual shift in sediment source from E/SE sources to southern source regions. Illite crystallinity data show that the shales within the Beetaloo Basin have experienced much greater temperatures than at present. Altree 2 has an XRD calculated bottom-hole temperature of 155°C at1647m depth, the Jamison records 156°C at 1695m with the Elliot being the hottest at 194°C at 1697 deep. These values were then used to calculate the amount of cover removed from present day. Altree 2 returned an estimate of 2050m of cover removed, Jamison 1769m and Elliot with the most cover removed at 2680m showing that the southern region of the Beetaloo Basin has experienced the greatest uplift since maximum subsidence followed by the northern Altree 2.
Thesis (B.Sc.(Hons)) -- University of Adelaide, School of Physical Sciences, 2017
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Smith, T. M. "‘McArthur’s Zircons, a Tale of Two Arenites’ – provenance and evolution of the Maiwok Sub-Group, McArthur Basin, Northern Territory." Thesis, 2016. http://hdl.handle.net/2440/121233.

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The Beetaloo Basin is a sub-basin of the ‘greater McArthur Basin’, a >180,000 km2 ca. 1800-900 Ma basin system that covers much of northern Australia and, in its Mesoproterozoic section, hosts extensive hydrocarbon reserves. The nature of the basin and provenance of the rocks within the basin are largely unknown. Here I present detrital zircon U-Pb data from twelve sandstone core samples from the Maiwok Sub-group, and compare them with existing outcrop samples from the Urapunga Region within the McArthur Basin to examine the maximum depositional ages of the formations, to address intra-basin correlation, and examine both temporal and spatial provenance variations. Detritus analysed yielded early Palaeoarchean to early Neoproterozoic ages from sandstone formations of the Maiwok Sub-group, in the Beetaloo Basin (Fig. 1). In the Beetaloo Basin; the Bessie Creek Sandstone formation was deposited between 1386 ± 13 Ma and 1324 ± 8 Ma, and the Moroak Sandstone formation was deposited after1375 ± 15 Ma. The formation logged as the Moroak Sandstone (320.0-391.72m) in Altree 2 drillcore was logged incorrectly. Detrital zircon data has shown this sandstone is too young to be the Moroak Sandstone. I have reinterpreted this interval in Altree 2 as Bukalorkmi Sandstone from 359.5-391.72m and Jamison Sandstone from 320.0-359.5m (Fig. 7). In Altree 2, the Bukalorkmi Sandstone was deposited after 1194 ± 25 Ma and the Jamison Sandstone was deposited between 959 ± 18 Ma and 513 ± 12 Ma. Temporal provenance variations are minimal between the Bessie Creek Sandstone and the Moroak Sandstone, but much greater between the Moroak Sandstone and the Jamison/Bukalorkmi Sandstone formations. The Walton High defines a spatial provenance boundary from the north and the south (Fig. 12). This boundary affects Maiwok Sub-group sandstones, including exposed formations, and has been under appreciated in previous studies.
Thesis (B.Sc.(Hons)) -- University of Adelaide, School of Physical Sciences, 2016
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Conference papers on the topic "Beetaloo Basin"

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Lupton, Nicholas, Regina Sander, Michael Camilleri, Zhejun Pan, and Luke Connell. "Characterisation of Reservoir Pressure and Temperature Impact on Diffusion Behaviour of Beetaloo Basin Shales." In SPE/AAPG/SEG Asia Pacific Unconventional Resources Technology Conference. Tulsa, OK, USA: Unconventional Resources Technology Conference, 2019. http://dx.doi.org/10.15530/ap-urtec-2019-198261.

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Donald, J. Adam, and Thomas J. Neville. "The Impact of Anisotropic Mechanical Properties on Stimulation and Wellbore Stability in the Beetaloo Basin, Northern Territory, Australia." In Asia Pacific Unconventional Resources Technology Conference 2021. Tulsa, OK, USA: Unconventional Resources Technology Conference, 2021. http://dx.doi.org/10.15530/ap-urtec-2021-208289.

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Crombez, Vincent, Marcus Kunzmann, Claudio Delle Piane, Mohinudeen Faiz, Stuart Munday, and Anne Forbes. "STRATIGRAPHIC ARCHITECTURE OF A PROTEROZOIC SHALE PLAY: INSIGHTS FROM WELL CORRELATION IN THE VELKERRI FORMATION (BEETALOO SUB-BASIN, NORTHERN TERRITORY, AUSTRALIA)." In GSA 2020 Connects Online. Geological Society of America, 2020. http://dx.doi.org/10.1130/abs/2020am-357071.

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Sander, Regina, Zhejun Pan, Luke D. Connell, Michael Camilleri, and Mihaela Grigore. "Controls on CH4 Adsorption on Shales: Characterisation of Beetaloo Sub-Basin Gas Shales and Comparison to Global Shales." In SPE Asia Pacific Oil and Gas Conference and Exhibition. Society of Petroleum Engineers, 2018. http://dx.doi.org/10.2118/191896-ms.

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