<div>GeoInsight was an 18-month pilot project developed in the latter part of Geoscience Australia’s Exploring for the Future Program (2016–2024). The aim of this pilot was to develop a new approach to communicating geological information to non-technical audiences, that is, non-geoscience professionals. The pilot was developed using a human-centred design approach in which user needs were forefront considerations. Interviews and testing found that users wanted a simple and fast, plain-language experience which provided basic information and provided pathways for further research. GeoInsight’s vision is to be an accessible experience that curates information and data from across Geoscience Australia, helping users make decisions and refine their research approach, quickly and confidently.</div><div><br></div><div>In the first iteration of GeoInsight, selected products for energy, minerals, water, and complementary information from Geoscience Australia’s Data Discovery Portal and Data and Publications Catalogue were examined to (1) gauge the relevance of the information they contain for non-geoscientists and, (2) determine how best to deliver this information for effective use by non-technical audiences.</div><div><br></div><div>This Record documents the technical details of the methods used for summarising energy commodities for GeoInsight. These methods were devised to convey current production and future production/extraction potential quickly and efficiently for regions across the Australian continent. Evaluated energy commodities include oil and gas, hydrogen and geological hydrogen storage, uranium and thorium, coal (black and brown), geothermal energy, and renewable energy. Carbon storage, a decarbonisation enabler, was also addressed under the energy theme.</div><div><br></div><div>This document contains two sections:</div><div><strong>Production Summary:</strong> To showcase where energy resources are being produced in different regions of Australia. The source datasets provide a snapshot of energy production activities at the time of publication. </div><div><strong>Potential Summary:</strong> To highlight, at first glance, the likelihood that future energy production and decarbonisation initiatives may occur in different regions of Australia. The source datasets provide a snapshot of future energy potential at the time of publication.</div><div><br></div><div>Any updates to the methodology used in GeoInsight will be accompanied by updates to this document, including a change log.</div><div>Geoscience Australia’s Exploring for the Future program provides precompetitive information to inform decision-making by government, community and industry on the sustainable development of Australia's mineral, energy and groundwater resources. By gathering, analysing and interpreting new and existing precompetitive geoscience data and knowledge, we are building a national picture of Australia’s geology and resource potential. This leads to a strong economy, resilient society and sustainable environment for the benefit of all Australians. This includes supporting Australia’s transition to net zero emissions, strong, sustainable resources and agriculture sectors, and economic opportunities and social benefits for Australia’s regional and remote communities. The Exploring for the Future program, which commenced in 2016, is an eight year, $225m investment by the Australian Government.</div><div><br></div>

<div>Australia’s Energy Commodity Resources (AECR) 2024 provides estimates of Australia’s energy commodity reserves, resources, and production as at the end of 2022. The 2024 edition of AECR also includes previously unpublished energy commodity resource estimates data compiled by Geoscience Australia for the 2022 reporting period. The AECR energy commodity resource estimates are based primarily on published open file data and aggregated (de-identified) confidential data. The annual assessment provides a baseline for the production and remaining recoverable resources of gas, oil, coal, uranium and thorium in Australia, and the global significance of our nation’s energy commodity resources. The publication also presents chapters on the status of emerging clean energy resources in Australia, including geothermal, carbon capture and storage (CCS) and hydrogen.</div>

<div>Geoscience Australia and CSIRO have collaborated, under the Exploring for the Future program, to investigate whether water-saturated residual oil zones (ROZs), sometimes associated with conventional Australian hydrocarbon plays, could provide a CO2 storage resource and enhance the storage capacity of depleted fields. This product is part of a larger project that includes, among others, a reservoir modelling component. </div><div>This report focuses on our petrophysical module of work that investigated the occurrence and character of ROZs in onshore Australian basins. Our findings demonstrate that ROZs occur in Australia’s hydrocarbon-rich regions, particularly in the Cooper-Eromanga Basin. ROZs with more than 10% residual oil saturation are uncommon, likely due to small original oil columns and lower residual saturations retained in sandstone reservoirs than in classic, carbonate-hosted North American ROZs. Extensive, reservoir-quality rock is found below the deepest occurring conventional oil in many of the fields in the Eromanga Basin, potentially offering significant CO2 storage capacity.&nbsp;</div><div>For more information about this project and to access the related studies and products, see: https://www.eftf.ga.gov.au/carbon-co2-storage-residual-oil-zones. </div><div><br></div>

CO₂ enhanced oil recovery (CO₂-EOR) is a proven technology that can extend the life of oil fields, permanently store CO₂, and improve the recovery of oil and condensate over time. Although CO₂-EOR has been used successfully for decades, particularly in the United States, it has not gained traction in Australia to date. In this study, we assemble and evaluate data relevant to CO₂-EOR for Australia’s key oil and condensate producing basins, and develop a national-scale, integrated basin ranking that shows which regions have the best overall conditions for CO₂-EOR. The primary goals of our study are to determine whether Australia’s major hydrocarbon provinces exhibit suitable geological and oil characteristics for successful CO₂-EOR activities and to rank the potential of these basins for CO₂-EOR. Each basin is assessed based on the key parameters that contribute to a successful CO₂-EOR prospect: oil properties (API gravity), pressure, temperature, reservoir properties (porosity, permeability, heterogeneity), availability of CO₂ for EOR operations, and infrastructure to support EOR operations. The top three ranked basins are the onshore Bowen-Surat, Cooper-Eromanga and offshore Gippsland Basins, which are all in relatively close proximity to the large east coast energy/oil markets. A significant factor that differentiates these three basins from the others considered in this study is their relatively good access to CO₂ and well-developed infrastructure. The next three most suitable basins are located offshore on the Northwest Shelf (Browse, Carnarvon, and Bonaparte Basins). While these three basins have mostly favourable oil properties and reservoir conditions, the sparse CO₂ sources and large distances involved lead to lower scores overall. The Canning and Amadeus Basins rank the lowest among the basins assessed, being relatively immature and remote hydrocarbon provinces, and lacking the required volumes of CO₂ or infrastructure to economically implement CO₂-EOR. In addition to ranking the basins for successful implementation of CO₂-EOR, we also provide some quantification of the potential recoverable oil in the various basins. These estimates used the oil and condensate reserve numbers that are available from national databases combined with application of internationally observed tertiary recovery factors. Additionally, we estimate the potential mass of CO₂ that would be required to produce these potential recoverable oil and condensate resources. In the large oil- and condensate-bearing basins, such as the Carnarvon and Gippsland Basins, some scenarios require over a billion tonnes of CO₂ to unlock the full residual resource, which points to CO₂ being the limiting factor for full-scale CO₂-EOR development. Even taking a conservative view of the available resources and potential extent of CO₂-EOR implementation, sourcing sufficient amounts of CO₂ for large-scale deployment of the technology presents a significant challenge. <b>Citation:</b> Tenthorey, E., Kalinowski, A., Wintle, E., Bagheri, M., Easton, L., Mathews, E., McKenna, J., Taggart, I. 2022. Screening Australia’s Basins for CO2-Enhanced Oil Recovery (December 6, 2022). <i>Proceedings of the 16th Greenhouse Gas Control Technologies Conference (GHGT-16) 23-24 Oct 2022</i>, Available at SSRN: <a href="https://ssrn.com/abstract=4294743">https://ssrn.com/abstract=4294743</a> or <a href="http://dx.doi.org/10.2139/ssrn.4294743">http://dx.doi.org/10.2139/ssrn.4294743</a>

<div>Geoscience Australia and CSIRO have collaborated, under the Exploring for the Future program, to investigate whether water-saturated residual oil zones (ROZs), sometimes associated with conventional Australian hydrocarbon plays, could provide a CO2 storage resource and enhance the storage capacity of depleted fields. This product is part of a larger project that includes, among others, a petrophysical study to identify and characterise ROZs. </div><div>In this report, we model the formation of a residual oil zone in an Australian setting and the subsequent injection of CO2 using a 5 spot well pattern. The reservoir is built as an archetype example of the Hutton Formation from the Cooper-Eromanga basin. The reservoir interval is populated with "permeable sandstone” and “impermeable baffle” facies and a sealing layer at the top of the model is created and assigned properties such that it can be made to leak oil by capillary failure, as part of the process used to create a residual oil column. The static model is them imported into CMG-GEM software for the reservoir flow simulations.&nbsp;We find the scenario, with injectors perforated at the top and a central producing well perforated at the bottom, able to both store the most CO2 and produce the most oil. The storage and sweep efficiencies are high, highlighting the difference with typical CO2 storage scenarios without pressure mitigation.</div><div>For more information about this project and to access the related studies and products, see: https://www.eftf.ga.gov.au/carbon-co2-storage-residual-oil-zones. </div> <b>Data is available on request from clientservices@ga.gov.au - Quote eCat# 149366</b>

<div>Carbon capture and storage (CCS) is gaining momentum globally. The Global CCS Institute notes in their Status of CCS 2023 report that there are 26 carbon capture and storage projects under construction and a further 325 projects in development, with a total capture capacity of 361 million tonnes per year (Mt/y) of carbon dioxide (CO2). Some CCS projects require the extraction of brackish or saline water (referred to here on in as brine) from the storage formation to manage increased pressure resulting from CO2 injection and/or to optimise subsurface storage space. It is important to consider the management of extracted brine as the CCS industry scales up due to implications for project design, cost and location as well as for the responsible management of the ‘waste’ or by-product brine. The use and disposal of reservoir brine has been investigated for CCS projects around the world, but not for Australian conditions. We have undertaken this review to explore how extracted brine could potentially be managed by CCS projects across Australia.&nbsp;</div>

<div>The Vlaming Sub-Basin CO2 Storage Potential Study data package includes the datasets associated with the study in the Vlaming Sub-basin, located within the southern Perth Basin about 30 km west of Perth. The data in this data package supports the results of the Geoscience Australia Record 2015/009 and appendices. The study provides an evaluation of the CO2 geological storage potential of the Vlaming Sub-basin and was part of the Australian Government's National Low Emission Coal Initiative.</div>

Australia is well-positioned to remain a global energy supplier and be a leader in driving efforts to achieve net-zero greenhouse gas emissions. Australia has the potential to produce a range of low emissions energy commodities such as geothermal energy, natural and manufactured hydrogen, and natural gas linked with carbon capture and storage. Our ample solar and wind energy resources also support the deployment of renewable energy technologies across the country. Our geological systems supply the raw materials — such as several of the critical minerals and strategic materials — that are needed to develop the infrastructure and manufacture the batteries and technologies that will support the energy transition. New and emerging opportunities have been identified for energy storage for energy produced from renewable sources, such as through manufacturing hydrogen, hydrogen storage in underground salt caverns, and compressed air energy storage. Australia is recognised for having a large potential to geologically store carbon dioxide. Carbon capture and storage technology can support industries that find it difficult to abate their emissions, including efforts to remove carbon dioxide directly from the atmosphere through use of direct air capture technology. Understanding the prospectivity for these resources and the current and emerging energy storage technologies will help to accelerate Australia's journey to a net-zero economy. As Australia’s national public sector geoscience organisation, Geoscience Australia continues to undertake national and regional research and data acquisition, to provide precompetitive data that underpins decision-making by governments and industry and attracts future investment.

<div>Identifying potential basin areas for future Geological Storage of CO2 (GSC) exploration is essential to support Australia’s transition to a net zero emissions energy future. Geoscience Australia’s AFER Project has completed a play-based assessment of the GSC potential in the Pedirka and western Eromanga basins using regionally extensive aquifers containing saline to slightly brackish formation waters. There are currently no significant anthropogenic CO2 sources or associated storage projects in the assessment area. Understanding the area’s GSC potential does, however, assist in providing options for addressing CCS requirements in the central Australian region, including any future opportunities to remove anthropogenic CO2 using Direct Air Capture and Storage technologies. </div><div><br></div><div>The AFER Project’s assessments are underpinned by new geological insights into the basins and a supporting upscaled 3D geological model. A play-based common risk segment mapping approach has been applied to five potential storage (play) intervals to delineate basin areas with relatively high prospectivity based on four geological risk elements: injectivity, storage effectiveness, containment, and structural complexity. Results from this qualitative component of the assessment highlights a potentially prospective area for future GSC exploration extending across the Northern Territory, South Australia and Queensland. The most prospective interval on a geological probability of success basis is the Namur-Murta play interval. </div><div><br></div><div>Results from the qualitative GSC assessment have been used as a screening tool to delineate areas for quantitative modelling of the range of Estimated Ultimate Storage (EUS) volumes using deterministic and probabilistic methodologies. EUS volumes have been estimated in two model areas representing geological end members in storage interval heterogeneity and potentially prospective areas outside of the extents of current national parks. The EUS potential is high (10’s of gigatonnes) in the two model areas using both deterministic and probabilistic workflows, as expected for a regional assessment using very large pore volumes. Applying a geological probability of success based on injectivity and structural and stratigraphic containment reduces the volumes in the two model areas to a risked best estimate EUS of 13 Gt in the eastern area and a risked best estimate EUS of 2 Gt in the western area. Results from the quantitative assessment suggest that both model areas can support multiple industrial-scale CCS projects injecting 50 Mt CO2 over a 20-year period. However, heterogeneous reservoirs that extend over the eastern assessment area are likely to have greater storage efficiencies and an associated smaller project footprint of 29 km2 using three CO2 injection wells. Relatively homogenous reservoirs elsewhere in the assessment area have lower storage efficiencies due to a lack of intraformational seals within the Algebuckina Sandstone and have an associated larger project area of 49 km2 using three CO2 injection wells. Pressure management requirements are likely to be minimal in both model areas due to the thick and open nature of reservoirs. However, water production rates of up to 16,500 m3/day may be required where local lateral barriers to pressure dissipation occur. &nbsp;&nbsp;&nbsp;</div><div><br></div><div>Results from the AFER Project's GSC assessment demonstrate the value of applying a play-based exploration workflow for a regional-scale energy resource assessment. Estimating the geological probability of success to the presence and repeatability of four mappable risk elements associated with GSC resources allows both relative prospectivity maps and risked EUS volumes to be generated. Prospectivity maps and EUS volumes can in turn be readily updated as new geological data are collected to infill data and knowledge gaps. Geoscience Australia is building a national inventory of GSC resources using this play-based exploration approach, with qualitative assessments now completed under the EFTF and TEGI programs in seven basin areas from central and eastern Australia.&nbsp;</div><div><br></div>