This dataset is a reference system for petroleum exploration and development wells drilled in Western Australia. NOTE: Since 1 January 2012 Offshore wells have been managed by National Offshore Petroleum Titles Administrator (NOPTA). NOPTA should be contacted for currency and completeness of offshore wells since this date. The extent of wells is both onshore and offshore (prior to 1/1/2012). Onshore wells are updated on a regular basis. Offshore is done on an adhoc basis when updates are provided by NOPTA.

During 2023, Western Australia produced the largest amount of crude oil and condensate at 21.3 million and 48 million barrels respectively. By comparison, only around 3.2 million barrels of crude oil had been produced in Victoria.

The Oil and Gas fields (points) is a dataset which contains a point representation of the location of oil and gas fields for display on map products. Show full description

As at September 2024, the capital expenditure of liquefied natural gas (LNG) investment in Western Australia reached around 30 billion Australian dollars. A further 38.6 billion Australian dollars of possible further investment was planned.

Petroleum Titles of all types which no longer have a status of current. The data is held in GDA2020 latitude and longitude coordinates Petroleum Titles of all types which no longer have a status of current. The data is held in GDA2020 latitude and longitude coordinates

Wandagee No. 1 Well was located in the Carnarvon Basin, Western Australia, approximately 84 miles north-east of Carnarvon. The well was drilled by Oil Drilling and Exploration CVV.A.) Fty Limited for West Australian Petroleum pty Limited, to a total depth of 3521 feet. Drilling commenced on 25th April, 1962 and was completed on 12th June, 1962. A full programme of logging, testing, and coring was undertaken.

The well was sited on a shallow part of the Wandagee Ridge. After drilling through 26 feet of Quaternary sand, the well penetrated 556 feet of a normal Carvarvon Basin sequence of Cretaceous sediments. The Upper Devonian Gneudna Formation was encountered at 591 feet, and this was followed from 912 feet by a section ranging in age from Silurian to possible Ordovician. The well bottomed at 3521 feet in the Tumblagooda Sandstone after drilling through 861 feet of the formation.

The primary objective of the well was to investigate the stratigraphy and oil potential of the Devonian and older rocks on a shallow part of the Wandagee Ridge. Traces of gas were observed in the marine siltstone unit at the top of the Tumblagooda Sandstone (2870 to 3098 feet), but no other hydrocarbon shows were recorded. Four drillstem tests recovered only brackish to salt water, The well was completed as a water well for Wandagee Station.

The off-structure drilling operation at Wandagee No. 1 was subsidized under the Petroleum Search Subsidy Act 1959-1961, from surface to total depth.

Jurien No. 1 Well was located on the western margin of the Perth Basin, Western Australia, approximately 76 miles south-south-east of Geraldton. The well was drilled by Oil Drilling and Exploration (W.A.) Fty Limited for West Australian Petroleum Fty Limited, to a total depth of 3366 feet. Drilling commenced on 9th July, 1962, and was completed on 21st August, 1962. A full programme of logging, testing, and coring was undertaken.

The well was spudded in the Coastal Limestone of Pleistocene age, and penetrated 811 feet of Lower Triassic Kockatea Shale; 2274 feet of Permian (Artinskian) sediments; 35 feet of (1) Permian sandstone, and entered Precambrian granitic gneiss at 3208 feet.

The well was drilled to investigate the stratigraphy and petroleum potential of the Permian sediments in the Jurien Anticline. At least 200 feet of structural closure over eight square miles were proved for that area on the basement refractor. The main objectives were the sandstones in the Irwin River Coal Measures and High Cliff Sandstone. No potential reservoir beds were observed and only the Lower Triassic Kockatea Shale appeared to be a good source rock for hydrocarbons although minor oil traces were observed in some of the Permian section.

Three drillstem tests were carried out over the intervals 552 to 595 feet, 1940 to 2020 feet, and 2196 to 2356 feet. No water, oil, or gas was recovered in any of the tests.

The stratigraIilic drilling operation at Jurien No. 1 was subsidized under the Petroleum Search Subsidy Act 1959-1961, from surface to total depth.

Sue No. 1 Well was located in the southern Perth Basin, Western Australia, about 150 miles South-south-west of Perth and sixteen miles east of the town of Margaret River. The well was drilled by Oil Drilling and Exploration Limited for West Australian Petroleum Pty Limited, to total depth of 10,097 feet. Drilling commenced on 31st January, 1986 and was completed on 5th March, 1966. A full programme of coring and logging was undertaken; no drillstem testing was conducted.

The well penetrated sediments equated to the Lower Cretaceous - Upper Jurassic Yarragadee Formationfrom surface to 3730 feet, and then entered Permian sandstones. Formation affinities have not yet baen definitely established, but these sediments may be correlatable with parts of the Permian section in the Collie Basin, an outlier in the Precambrian Shield to the north-east.

The Permian rocks, 6291 feet thick in Sue No. I, are salt-water bearing (average 20,000 ppm. NaCl). Small gas shows of methane were associated with carbonaceous sections. An igneous intrusive body, 22 feet thick, of dolerite was intersected at 9390 feet. A small gas show of methane and ethane was recorded immediately below these rocks, and traces of fluorescence Were noted in the underlying sandstones. However, the rocks in which these shows occurred were tight and impermeable.

A thin, basal conglomerate was intersected before drilling into Precambrian basement at 10,021 feet. The well reached total depth at 10,097 feet in these matamorphic rocks.

Sue No. 1 was drilled near the crest of an anticline, located by seismic surveys carried out in 1964-1965. The well was programmed to test the stratigraphy and hydrocarbon bearing potential of the Mesozoic and Palaeozolc sediments in this little-known area, near the western margin of the southern Perth Basin, in a graben bounded by major faults to the west and east. Only minor shows of gas were recorded while drilling Sue No. I, and the well was plugged and abandoned.

The stratigraphic drilling operation at Sue No. 1 was subsidized under the Petroleum Search Subsidy Act 1959-1964, from surface to total depth.

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This report on the Perth Basin, Western Australia, is the tenth in the Australian Petroleum Accumulation Series. The series presents data on Australia's identified petroleum resources, together with an appraisal of their geological setting, hydrocarbon habitat and characteristics. In the case of commercial accumulations, details of their size, development and production history are included. The APA database, on which this series is based, was developed in cooperation with petroleum companies and State and Northern Territory Mines Departments. It is linked to PEDIN, the publicly available petroleum exploration information database maintained jointly by the Bureau of Resource Sciences and the Australian Geological Survey Organisation.

In the financial year of 2020, the sales volume of hydraulic engine industrial oil in Western Australia, was approximately 7.4 megaliters. In contrast, the sales volume for gear industrial oils in Western Australia was about 2.8 megaliters.

As at January 1993, nineteen hydrocarbon accumulations, six of which are commercial, have been discovered in the Canning Basin. The commercial accumulations occur in Permian to Devonian reservoirs on an area of relatively shallow basement (Lennard Shelf) flanking the northern margin of the Fitzroy Trough. Oil is produced from Famennian reefs, associated drape structures, and four-way dip closures in Permo-carboniferous, Grant Group and Anderson Formation sandstones. The most likely sources of these hydrocarbons are Late Devonian and Carboniferous marine shales in the Fitzroy Trough kitchen area. The small size of the accumulations in the Canning basin (less than 0.5 million barrels of recoverable oil) precludes the development of large infrastructure projects. Oil is trucked to the storage and shiploading facilities at Broome and then shipped to the Kwinana oil refinery in Western Australia. On the southern margin of the Fitzroy Trough, oil and gas have been recovered from a transgressive Ordovician sequence of sandstones shales and carbonates. Although the Ordovician has yet to yield a commercial discovery, Devonian reef plays in the overlying section may enhance the attractiveness of Ordovician objectives in this area. To date, exploration effort in the basin has been largely directed to the northern, onshore Canning Basin. The offshore Canning and the Kidson Sub-basin remain underexplored. Higher risk plays in these areas have yet to be adequately tested.

Sahara No. 1 Well was proposed as a 10,000 - foot stratigraphic test to explore and to evaluate the hydrocarbon potential of Permian and pre-Permian sediments within the gentle structural depression of the Kidson Basin, south-western Canning Basin, Western Australia, at a location approximately 300 miles east-south-east of Port Hedland. The well, located about 178 miles south-east of Samphire Mirsh No. I, was drilled by Drilling Contractors (Aust.) pty Ltd for West Australian Petroleum pty Limited to total depth of 6956 feet. Drilling commenced on 11th January, 1965 and was suspended on 26th February, 1965. A full programme of coring and logging was undertaken; no drillstem testing was conducted, as none was warranted for evaluation.

The well penetrated Recent sands from surface to 40 feet, undifferentiated Mesozoic sediments to 195 feet, which were followed by a normal Permian (Artinskian and Sakmarian) sequence, and entered the Devonian at 30':>5 feet. Drilling operations were suspended at 6956 feet in an undated evaporitic section encountered at 6670 feet. This interbedded evaporite-red bed unit exhibited swelling and sloughing properties in reaction with the drilling mud, and allowed only limited and hazardous penetration during the final three weeks of operation. These circumstances forced the suspension of Sahara No. 1 short of programmed depth, with an unknown thickness of sediments remaining unpenetrated.

The Devonian and older sequence found in Sahara No. 1 had not been encountered elsewhere, and three new formations were established. Absence of microfossils prevents age assignment for the basal 3256 feet of red beds found below the upper limestone of probable Middle Devonian age.

Sahara No. I, although suspended above its programmed depth because of insurmountable drilling conditions, has contributed significant stratigraphic information, provided a comprehensive evaluation 0:1: potential hydrocarbon reservoirs which were water-saturated at this location, and established a geological tie to substantial depth for the extensive geophysical surveys which have been conducted within the region.

The stratigraphic drilling operation at Sahara No. 1 was subsidized under the Petroleum Search Subsidy Act 1959-1964, from surface to total depth.

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Eneabba No. 1 Well was located in the northern part of the Perth Basin, Western Australia, approximately 32 miles south-east of Dongara. The well was drilled by Oil Drilling and Exploration (W.A.) Pty Limited for West Australian Petroleum Pty Limited, to a total depth of 13,712 feet. Drilling commenced on 12th June, 1961 and was completed on 25th November, 1961. A full programme of logging and coring was undertaken. After drilling through 28 feet of Quaternary alluvium, the well penetrated 5558 feet of Lower Cretaceous to Middle Jurassic Yarragadee Formation, 276 feet of Middle Jurassic probable Cadda Formation equivalent, 3894 feet of Lower Jurassic to Upper Triassic Cockleshell Gully Formation, 960 feet of Upper Triassic Lesueur Sandstone, 436 feet of Middle to Lower Triassic Woodada Formation, and 2548 feet of Lower Triassic Kockatea Shale. The pipe stuck at 5275 feet when starting to pull out at 13,712 feet, and eventually the well was abandoned leaving 9200 feet of drill string in the hole. The well was drilled to investigate the petroleum potential and stratigraphy of the Mesozoic and Palaeozoic sediments in the northern part of the Perth Basin. The Mesozoic section was much thicker than expected at the well which had not reached the Palaeozoic when abandoned at 13,712 feet because of mechanical difficulties. Many oil shows and one strong gas show (from a fracture zone between 12,795 and 12,800 feet) were recorded in the Kockatea Shale but no formation tests were carried out because of the impervious nature of the formation. The stratigraphic drilling operation at Eneabba No. 1 was subsidized under the Petroleum Search Subsidy Act 1959, from surface to total depth.

The Oils of Western Australia II report summarises the findings of a collaborative research program between Geoscience Australia and GeoMark Research undertaken on the petroleum geochemistry of crude oils and condensates discovered within the basins of western Australia and the Papuan Basin, Papua New Guinea prior to March 2000. The interpretations documented herein build on research that Geoscience Australia and GeoMark Research undertook previously in The Oils of Western Australia (AGSO and GeoMark, 1996) and The Oils of Eastern Australia (Geoscience Australia and GeoMark, 2002) studies. To make informed decisions regarding Australia's petroleum resources, it is important to understand the relationship between the liquid hydrocarbons within and between basins. This Study has geochemically characterised the liquid hydrocarbon accumulations of western Australian basins and the Papuan Basin into genetically related families. From a total of 316 samples, 33 oil/condensate families were identified in the western Australian basins; Bonaparte (10), Browse (2), Canning (4), Carnarvon (11) and Perth (6), as well as some vagrant and contaminated samples. Three oil/condensate families were recognised in the Papuan Basin. The geographic distribution of each oil/condensate family is mapped within each basin/sub-basin. Using the geochemical characteristics of each family, the nature of their source facies, thermal maturity level and degree of preservation has been determined. This Study used a set of standardised geochemical protocols that include bulk geochemical (API gravity, elemental analysis of nickel, vanadium and sulphur), molecular (gas chromatography of the whole-oil and gas chromatography-mass spectrometry of the saturated and aromatic hydrocarbons) and bulk stable carbon isotopic analyses. n-Alkane-specific 13C isotopic analyses were carried out on only a selected set of oils and condensates. Statistical analyses were performed on these data using the software Pirouette provided by Infometrix. In addition to this report, the geochemical data acquired for the crude oils and condensates in this Study are provided in the accompanying Microsoft Access2000 database. These data may be viewed spatially and plotted on x-y cross-plots in the charting application included in the ESRI Australia GIS ArcView3.2 georeferencing package that also accompanies this report.

Legacy product - no abstract available You can also purchase hard copies of Geoscience Australia data and other products at http://www.ga.gov.au/products-services/how-to-order-products/sales-centre.h…Show full descriptionLegacy product - no abstract available You can also purchase hard copies of Geoscience Australia data and other products at http://www.ga.gov.au/products-services/how-to-order-products/sales-centre.html

Graph and download economic data for Gross Domestic Product: Petroleum and Coal Products Manufacturing (324) in Washington (WAPETCOALMANNGSP) from 1997 to 2023 about coal, petroleum, nondurable goods, WA, GSP, private industries, production, goods, private, manufacturing, industry, GDP, and USA.

Gasoline Price: Pilbara data was reported at 189.600 0.01 AUD/l in Apr 2025. This records a decrease from the previous number of 190.400 0.01 AUD/l for Mar 2025. Gasoline Price: Pilbara data is updated monthly, averaging 150.550 0.01 AUD/l from Jan 2001 (Median) to Apr 2025, with 292 observations. The data reached an all-time high of 219.900 0.01 AUD/l in Oct 2023 and a record low of 95.800 0.01 AUD/l in Jan 2002. Gasoline Price: Pilbara data remains active status in CEIC and is reported by Department of Mines, Industry Regulation and Safety. The data is categorized under Global Database’s Australia – Table AU.P008: Average Petrol and Diesel Prices: Western Australia.

A reconnaissance marine reflection seismic survey was conducted hi Exmouth Gulf and the open coastal waters along the west coast of Western Australia from Frazer Island to Bernier Island (see Fig. 1).

The survey was a two-boat operation. The survey in the Exmouth Gulf area was controlled by a Lorac radio navigational system, and along the west coast positioning was determined by sextant angle measurements to shore beacons and landmarks. All shots were recorded on magnetic tapes which were processed into variable area record sections.

The following maps were constructed: (i) On a Horizon "A" within the Upper Cretaceous Korojon Calcarenite (Exmouth Gulf area only); (ii) On a Horizon "B" near the Basal Cretaceous unconformity; (iii) On pre-Cretaceous structure; (iv) Time interval between Horizons "A" and "B" (Exmouth Gulf area only); (v) Depth of water.

The Exmouth marine survey indicated that Exmouth Gulf is essentially synclinal in character in the Cretaceous and Tertiary sediments. Several major pra-Cretaceous fault trends which had already been mapped on land with the seismograph were followed beneath the Gulf. The pre-Cretaceous axis of the Cape Range Anticline was located both to the north and to the south of the surface expression of the structure. The chain of islands to the north-east of the Ca.pe Range are aligned on a structural trend.

To the south of-Point Maud, the Cuvier marine survey provided a much-needed tie between the Rough Range-Cape Range area and the structurally complex area around the Salt Marsh. Some structural leads were found in this southern area and the trend of major faults was established.

You can also purchase hard copies of Geoscience Australia data and other products at http://www.ga.gov.au/products-services/how-to-order-products/sales-centre.html