Recent national and state assessments have concluded that sedimentary formations that underlie or are within the Great Artesian Basin (GAB) may be suitable for the storage of greenhouse gases. These same formations contain methane and naturally generated carbon dioxide that has been trapped for millions of years. The Queensland government has released exploration permits for Greenhouse Gas Storage in the Bowen and Surat basins. An important consideration in assessing the potential economic, environmental, health and safety risks of such projects is the potential impact CO2 migrating out of storage reservoirs could have on overlying groundwater resources. The risk and impact of CO2 migrating from a greenhouse gas storage reservoir into groundwater cannot be objectively assessed without knowledge of the natural baseline characteristics of the groundwater within these systems. Due to the phase behaviour of CO2, geological storage of carbon dioxide in the supercritical state requires depths greater than 800m, but there are no hydrochemical studies of such deeper aquifers in the prospective storage areas. Geoscience Australia (GA) and the Geological Survey of Queensland (GSQ), Queensland Department of Mines and Energy, worked collaboratively under the National Geoscience Agreement (NGA) to characterise the regional hydrochemistry of the Denison Trough and Surat Basin and trialled different groundwater monitoring strategies. The output from this Project constitutes part of a regional baseline reference set for future site-specific and semi-regional monitoring and verification programmes conducted by geological storage proponents. The dataset provides a reference of hydrochemistry for future competing resource users.

Bores sunk at Cremorne in 1891 struck coal at approximately 2802 feet. A company was formed to work the coal, but was refused permission to operate at Cremorne. A site at Balmain was secured, and the Birthday Shaft was sunk to a depth of 2,937 feet between 1897 and 1902. This report provides an overview of the occurrence of natural gas and workings for the period 1897 to 1948. Gas yields, commercial production, leakage problems, and the use of testing to determine the behaviour of gas in the mine are the key subjects that are addressed in this report.

A major concern for regulators and the public with geologically storage of gas is the potential for the migration of gas (e.g. CO2) via a leaky fault or well into potable groundwater supplies. Given sufficient CO2, an immediate effect on groundwater would be a decrease in pH which could lead to accelerated weathering, an increase in alkalinity and the release of major and minor ions. Laboratory and core studies have demonstrated that on contact with CO2 heavy metals can be released under low pH and high CO2 conditions (particularly Pd, Ni and Cr). There is also a concern that trace organic contaminants could be mobilised due to the high solubility of many organics in supercritical CO2. These scenarios could potentially occur under a high CO2 leakage event but a small leak might be barely perceptible yet could provide an important early warning for a subsequent and more substantial impact. Different approaches are required for the detection and quantification of these low level leaks and are the subject of this paper. A 3 year groundwater survey was recently completed in the Surat Basin, which forms part of the Triassic-Cretaceous, Great Artesian Basin (GAB) aquifer sequence. In addition to a comprehensive water and isotopic analysis of samples from groundwater wells, gases were collected from groundwater samples and analysed for composition, '13CCO2, '13CCH4 and '2HCH4. Methane is prevalent in the major aquifers in the Surat Basin (e.g. Mooga, Gubbermunda and Hutton sandstones) and is invariably associated with a bacterial (methanogenic) carbonate reduction source, evident from its isotopic signature ('13CCH4 ~ -70', '2HCH4 ~ 220'). In addition to methane and low levels of CO2, trace levels of ethane are often detected.

The study provides a comprehensive analysis of the natural gases from the Bonaparte, Browse, Carnarvon and Perth basins (in 4 modules). Geochemical analyses for the molecular and carbon isotope composition were performed on 96 gases and associated liquids, and these data are interpreted in a geological context. Additional non-exclusive data from the AGSO database have been used for correlation/interpretation purposes. The study addresses factors influencing the composition of gaseous and other light hydrocarbons in natural gas (and associated oil accumulations) including; - primary source and maturity controls, - secondary alteration processes, e.g. migration fractionation, water washing, biodegradation, and - multiple charge histories, including deep dry gas inputs.

This report is a summary of information collected between November, 1948 and July, 1949 in the course of visits to the United Kingdom and the United States. The main subjects investigated were the complete gasification of coal, particularly in respect of its application to Victorian brown coal, the production of oil by synthesis and the production and refining of shale oil. Information was sought on a considerable number of other interests in the field of fuel technology as the opportunity offered. The authorities consulted were invariably experts in their respective fields, and great care was taken to record their information accurately. The report is a summary of recent developments and not an exhaustive study of the subjects mentioned. A considerable mass of detail has been excluded but is available on record for further reference.

Map of Australia showing the distribution of black coal, brown coal and Coal Seam Gas bearing basins overlain by prohibited areas. This map and enlargements of the Sydney, Bowen/Surat and Arckaringa basins were provided to DoFD as part advice regarding CSG exploration and coal extraction on commonwealth lands. These maps and their subsets are in 'DRAFT' form and are for internal use only.

This Oil and Gas Resources of Australia 2010 publication is the successor to Oil and Gas Resources of Australia 2009 and continues as the definitive reference on exploration, development and production of Australia's petroleum resources. The tables describe: - wells drilled - seismic surveys - petroleum discoveries - petroleum reserves - production and development, including forecasts of crude oil and condensate and a listing of offshore facilities

This point dataset contains offshore Oil and Gas Platforms located in Australian waters that include infrastructure facilities for the extraction, processing and/or storage of oil and natural gas.

<div>Australia’s Energy Commodity Resources (AECR) provides estimates of Australia’s energy commodity reserves, resources, and production as at the end of 2021. The 2023 edition of AECR also includes previously unpublished energy commodity resource estimates data compiled by Geoscience Australia for the 2021 reporting period. The AECR energy commodity resource estimates are based primarily on published open file data and aggregated (de identified) confidential data. The 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.</div>

The Oil and Gas Pipelines service contains known spatial locations of onshore and offshore pipelines or pipeline corridors used to transport natural gas, oil and other liquids within Australia’s mainland and territorial waters.