Emerging unconventional shale plays in Western Australia

Production of shale gas in the US has changed its position from a gas importer to a potential gas exporter. This has stimulated exploration for shale-gas resources in WA. The search started with Woodada Deep–1 (2010) and Arrowsmith–2 (2011) in the Perth Basin to evaluate the shale-gas potential of the Permian Carynginia Formation and the Triassic Kockatea Shale, and Nicolay–1 (2011) in the Canning Basin to evaluate the shale-gas potential of the Ordovician Goldwyer Formation. Estimated total shale-gas potential for these formations is about 288 trillion cubic feet (Tcf). Other petroleum source rocks include the Devonian Gogo and Lower Carboniferous Laurel formations of the Canning Basin, the Lower Permian Wooramel and Byro groups of the onshore Carnarvon Basin, and the Neoproterozoic shales of the Officer Basin. The Canning and Perth basins are producing petroleum, whereas the onshore Carnarvon and Officer basins are not producing, but they have indications for petroleum source rocks, generation, and migration from geochemistry data. Exploration is at a very early stage, and more work is needed to estimate the shale-gas potential of all source rocks and to verify estimated resources. Exploration for shale gas in WA will benefit from new drilling and production techniques and technologies developed during the past 15 years in the US, where more than 102,000 successful gas production wells have been drilled. WA shale-gas plays are stratigraphically and geochemically comparable to producing plays in the Upper Ordovician Utica Shale, Middle Devonian Marcellus Shale and Upper Devonian Bakken Formation, Upper Mississippian Barnett Shale, Upper Jurassic Haynesville-Bossier formations, and Upper Cretaceous Eagle Ford Shale of the US. WA is vastly under-explored and emerging self-sourcing shale plays have revived onshore exploration in the Canning, Carnarvon, and Perth basins.

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The concept of well integrity in gas production activities

Ecological Chemistry and Engineering S ◽

10.1515/eces-2016-0013 ◽

2016 ◽

Vol 23 (2) ◽

pp. 205-213 ◽

Cited By ~ 1

Author(s):

Peter Reichetseder

Keyword(s):

Drinking Water ◽

Shale Gas ◽

Environmental Protection Agency ◽

Marcellus Shale ◽

The United States ◽

Gas Production ◽

Well Integrity ◽

Drinking Water Resources ◽

The Us ◽

Geological Situation

Abstract Shale gas production in the US, predominantly from the Marcellus shale, has been accused of methane emissions and contaminating drinking water under the suspicion that this is caused by hydraulic fracturing in combination with leaking wells. Misunderstandings of the risks of shale gas production are widespread and are causing communication problems. This paper discusses recent preliminary results from the US Environmental Protection Agency (EPA) draft study, which is revealing fact-based issues: EPA did not find evidence that these mechanisms have led to widespread, systemic impacts on drinking water resources in the United States, which contrasts many broad-brushed statements in media and public. The complex geological situation and extraction history of oil, gas and water in the Marcellus area in Pennsylvania is a good case for learnings and demonstrating the need for proper analysis and taking the right actions to avoid problems. State-of-the-art technology and regulations of proper well integrity are available, and their application will provide a sound basis for shale gas extraction.

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New Hybrid Approach for Developing Automated Machine Learning Workflows: A Real Case Application in Evaluation of Marcellus Shale Gas Production

Fuels ◽

10.3390/fuels2030017 ◽

2021 ◽

Vol 2 (3) ◽

pp. 286-303

Author(s):

Vuong Van Pham ◽

Ebrahim Fathi ◽

Fatemeh Belyadi

Keyword(s):

Artificial Intelligence ◽

Machine Learning ◽

Shale Gas ◽

Field Data ◽

Marcellus Shale ◽

Hybrid Approach ◽

Gas Production ◽

Bayesian Optimization ◽

Real Field ◽

Engineering Problems

The success of machine learning (ML) techniques implemented in different industries heavily rely on operator expertise and domain knowledge, which is used in manually choosing an algorithm and setting up the specific algorithm parameters for a problem. Due to the manual nature of model selection and parameter tuning, it is impossible to quantify or evaluate the quality of this manual process, which in turn limits the ability to perform comparison studies between different algorithms. In this study, we propose a new hybrid approach for developing machine learning workflows to help automated algorithm selection and hyperparameter optimization. The proposed approach provides a robust, reproducible, and unbiased workflow that can be quantified and validated using different scoring metrics. We have used the most common workflows implemented in the application of artificial intelligence (AI) and ML in engineering problems including grid/random search, Bayesian search and optimization, genetic programming, and compared that with our new hybrid approach that includes the integration of Tree-based Pipeline Optimization Tool (TPOT) and Bayesian optimization. The performance of each workflow is quantified using different scoring metrics such as Pearson correlation (i.e., R2 correlation) and Mean Square Error (i.e., MSE). For this purpose, actual field data obtained from 1567 gas wells in Marcellus Shale, with 121 features from reservoir, drilling, completion, stimulation, and operation is tested using different proposed workflows. A proposed new hybrid workflow is then used to evaluate the type well used for evaluation of Marcellus shale gas production. In conclusion, our automated hybrid approach showed significant improvement in comparison to other proposed workflows using both scoring matrices. The new hybrid approach provides a practical tool that supports the automated model and hyperparameter selection, which is tested using real field data that can be implemented in solving different engineering problems using artificial intelligence and machine learning. The new hybrid model is tested in a real field and compared with conventional type wells developed by field engineers. It is found that the type well of the field is very close to P50 predictions of the field, which shows great success in the completion design of the field performed by field engineers. It also shows that the field average production could have been improved by 8% if shorter cluster spacing and higher proppant loading per cluster were used during the frac jobs.

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Study on the Forming Conditions of Shale Gas in Coal Measure of Wuli Area, Qinghai Province, China

Applied Mechanics and Materials ◽

10.4028/www.scientific.net/amm.295-298.2770 ◽

2013 ◽

Vol 295-298 ◽

pp. 2770-2773 ◽

Cited By ~ 3

Author(s):

Dai Yong Cao ◽

Jing Li ◽

Ying Chun Wei ◽

Xiao Yu Zhang ◽

Chong Jing Wang

Keyword(s):

Shale Gas ◽

Thermal Evolution ◽

Organic Matter Content ◽

Gas Production ◽

Matter Content ◽

Source Rocks ◽

Coal Measure ◽

Gas Generation ◽

Qinghai Province ◽

Coal Measures

Besides coal seam, the source rocks including dark mudstone, carbon mudstone and so on account for a large proportion in the coal measures. Based on the complex geothermal evolution history, the majority of coal measure organic matters with the peak of gas generation have a good potential of gas. Therefore, shale gas in coal measure is an important part of the shale gas resources. There are good conditions including the thickness of coal measures, high proportion of shale rocks, rich in organic matter content, high degree of thermal evolution, high content of brittle mineral and good conditions of the porosity and permeability for the generation of shale gas in Wuli area, the south of Qinghai province. Also the direct evidence of the gas production has been obtained from the borehole. The evaluation of shale gas in coal measure resources could broaden the understanding of the shale gas resources and promote the comprehensive development of the coal resources.

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Petroleum geochemistry, burial history and shale gas potential of the Goldwyer Formation - Canning Basin, Western Australia

International Journal of Oil Gas and Coal Technology ◽

10.1504/ijogct.2019.10020628 ◽

2019 ◽

Vol 20 (4) ◽

pp. 420

Author(s):

Lukman Johnson ◽

Reza Rezaee ◽

Nuno Pimentel ◽

Munther Alshakhs ◽

Amir Karimian Torghabeh

Keyword(s):

Western Australia ◽

Shale Gas ◽

Burial History ◽

Canning Basin ◽

Petroleum Geochemistry ◽

Gas Potential

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Quantitative Prediction of Radon Concentration at Wellhead in Shale Gas Development

SPE Journal ◽

10.2118/180358-pa ◽

2016 ◽

Vol 22 (01) ◽

pp. 235-243 ◽

Cited By ~ 3

Author(s):

Wei Tian ◽

Xingru Wu ◽

Tong Shen ◽

Zhenyu Zhang ◽

Sumeer Kalra

Keyword(s):

Natural Gas ◽

Numerical Simulations ◽

Shale Gas ◽

Radon Concentration ◽

Marcellus Shale ◽

Gas Production ◽

Influential Factors ◽

Natural Fracture ◽

Quantitative Prediction ◽

Radon Gas

Summary Hydraulic fracturing has been applied as an effective method to increase gas production from shale formations; however, this method has also raised concerns about its adverse impacts on environment. For example, in the Marcellus shale formation, some measured radon-gas concentrations exceeded the safe standard. Therefore, it is important to quantitatively evaluate radon concentration from fractured wells. However, existing researches have not successfully conducted a systematic and predictive study on the relationship between shale gas production and radon concentration at the wellhead of a hydraulically fractured well. To address this issue and quantitatively determine the radon concentration, we present the mechanisms of radon-gas generation and releasing, and conducted numerical simulations on its transport process in the subsurface formation system. The concentration of radon in produced gas is related with the original sources where the natural gas is extracted. Radon, generated from the radium alpha decay process, is trapped in pore spaces before the reservoir development. With the fluid flowing through the subsurface network, released radon will move to surface with the produced streams such as natural gas and flowback water. Our study shows that the radon concentration at wellhead could be significant. Influential factors such as natural-fracture-network properties, formation petrophysical parameters, and fracture dimension are investigated with sensitivity studies through numerical simulations. Analysis results suggest that radon wellhead concentration is strongly related with production rate. Thus, careful production design and protection are necessary to reduce radon hazard regarding the public and environmental impact.

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2012 PESA production and development review

The APPEA Journal ◽

10.1071/aj12013 ◽

2013 ◽

Vol 53 (1) ◽

pp. 165

Author(s):

Jeff Jurinak ◽

Bruce Anderson

Keyword(s):

Shale Gas ◽

Gas Production ◽

Policy Debate ◽

Development Environment ◽

Hydrocarbon Production ◽

North West ◽

The North ◽

Schedule Delay ◽

The Us ◽

Under Construction

2012 was a pivotal year for Australian petroleum development and production, during a dynamic time in our region, and globally. Australian activity headlines are LNG, the continuing pace and scale of the development of major projects, and record national petroleum production. LNG development in Australia is proceeding apace, with seven sanctioned projects under construction in WA and Queensland. The scale of the major projects underway is being felt with competition for skills, materials and services driving cost inflationary pressures and, coupled with other factors—such as an historically high Australian dollar—has resulted in several announced budget increases and schedule slippages. In addition, the regulatory framework is evolving, as regulators adapt to new industry trends and technologies. Proponents of future developments and expansions will be seeking to sanction in a tougher, but potentially better-informed development environment. Overall, national hydrocarbon production increased to a record high in 2012, attributable to a number of factors, but not least of which was the commissioning and successful start of commercial production of the Woodside-operated Pluto LNG development from the Pluto and Xena fields in the Carnarvon basin. Pluto was the first commissioned project since 2006, and may be viewed as the first of a number of developments that will be coming on-stream in the next few years, and will elevate Australia’s position in the ranking of world LNG production. Adding production from Pluto has allowed Woodside to take the lead position as the highest petroleum producer from BHP Billiton during 2012. Activity is not limited to LNG. Other highlights for 2012 included the opening of the Devil Creek project on the North West Shelf, WA’s third domestic gas hub, with the potential to supply around 20% of the state’s needs. Cost increase and schedule delay is not limited to LNG either, with Yolla mid-life enhancement and the Kipper offshore development facing cost and schedule pressure. In the broader global sphere, the highlight of 2012 is the extraordinary rise of unconventional oil in the US to the point of speculation about future US self-sufficiency. This parallels the rise of US unconventional gas in recent years, with gas supplies exceeding existing domestic demand and driving down the previously high domestic prices. Presently, only one US LNG project is approved for export; however, with an ongoing policy debate in the US about significant gas export verses retention to spur domestic growth, and favourable location of potential US access to the Asian market, the outcome is important for future competition to Australia’s cost-challenged LNG industry. Among this the announcement by Santos of the connection of the first shale gas well in Australia to sales delivery—albeit as an appraisal well—is a notable occurrence as a potential forerunner of shale gas production in Australia.

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Shale Gas Potential of Goldwyer Formation in Canning Basin, Australia

Proceedings of the International Field Exploration and Development Conference 2018 - Springer Series in Geomechanics and Geoengineering ◽

10.1007/978-981-13-7127-1_51 ◽

2019 ◽

pp. 560-572

Author(s):

Wenguang Zhao ◽

Yuxia Ma ◽

Houqin Zhu

Keyword(s):

Shale Gas ◽

Canning Basin ◽

Gas Potential

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Petroleum generation and expulsion characteristics of Lower and Middle Jurassic source rocks on the southern margin of Junggar Basin, northwest China: implications for unconventional gas potential

Canadian Journal of Earth Sciences ◽

10.1139/cjes-2013-0200 ◽

2014 ◽

Vol 51 (6) ◽

pp. 537-557 ◽

Cited By ~ 10

Author(s):

Jigang Guo ◽

Xiongqi Pang ◽

Fengtao Guo ◽

Xulong Wang ◽

Caifu Xiang ◽

...

Keyword(s):

Source Rock ◽

Shale Gas ◽

Middle Jurassic ◽

Junggar Basin ◽

Northwest China ◽

Source Rocks ◽

Coal Bed ◽

Southern Margin ◽

Petroleum Generation ◽

Gas Potential

Jurassic strata along the southern margin of Junggar Basin are important petroleum system elements for exploration in northwest China. The Lower and Middle Jurassic source rock effectiveness has been questioned as exploration progresses deeper into the basin. These source rocks are very thick and are distributed widely. They contain a high total organic carbon composed predominantly of Type III kerogen, with some Type II kerogen. Our evaluation of source rock petroleum generation characteristics and expulsion history, including one-dimensional basin modeling, indicates that Jurassic source rocks are gas prone at deeper depths. They reached peak oil generation during the Early Cretaceous and began to generate gas in the Late Cretaceous. Gas generation peaked in the Paleogene–Neogene. Source rock shales and coals reached petroleum expulsion thresholds at thermal maturities of 0.8% and 0.75% vitrinite reflectance, respectively, when the petroleum expulsion efficiency was ∼40%. The petroleum generated and expelled from these source rocks are 3788.75 × 108 and 1507.55 × 108 t, respectively, with a residual 2281.20 × 108 t retained in the source rocks. In these tight reservoirs, a favorable stratigraphic relationship (where tight sandstone reservoirs directly overlie the source rocks) indicates short vertical and horizontal migration distances. This indicates the potential for a large, continuous, tight-sand gas resource in the Lower and Middle Jurassic strata. The in-place natural gas resources in the Jurassic reservoirs are up to 5.68 × 1012 − 15.14 × 1012 m3. Jurassic Badaowan and Xishanyao coals have geological characteristics that are favorable for coal-bed methane resources, which have an in-place resource potential between 3.60 × 1012 and 11.67 × 1012 m3. These Lower and Middle Jurassic strata have good shale gas potential compared with active US shale gas, and the inferred in-place shale gas resources in Junggar Basin are between 20.73 × 1012 and 113.89 × 1012 m3. This rich inferred conventional and unconventional petroleum resource in tight-sand, coal-bed, and shale gas reservoirs makes the deeper Jurassic strata along the southern margin of Junggar Basin a prospective target for future exploration.

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