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Author: Grafiati

Published: 10 December 2022

Last updated: 29 January 2023

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1

Menpes, Sandra, and Tony Hill. "Emerging continuous gas plays in the Cooper Basin, South Australia." APPEA Journal 52, no. 2 (2012): 671. http://dx.doi.org/10.1071/aj11085.

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Recent off-structure drilling in the Nappamerri Trough has confirmed the presence of gas saturation through most of the Permian succession, including the Roseneath and Murteree shales. Basin-centred gas, shale gas and deep CSG plays in the Cooper Basin are now the focus of an escalating drilling and evaluation campaign. The Permian succession in the Nappamerri Trough is up to 1,000 m thick, comprising very thermally mature, gas-prone source rocks with interbedded sands—ideal for the creation of a basin-centred gas accumulation. Excluding the Murteree and Roseneath shales, the succession comprises up to 45% carbonaceous and silty shales and thin coals deposited in flood plain, lacustrine and coal swamp environments. The Early Permian Murteree and Roseneath shales are thick, generally flat lying, and laterally extensive, comprising siltstones and mudstones deposited in large and relatively deep freshwater lakes. Total organic carbon values average 3.9% in the Roseneath Shale and 2.4% in the Murteree Shale. The shales lie in the wet gas window (0.95–1.7% Ro) or dry gas window (>1.7% Ro) over much of the Cooper Basin. Thick Permian coals in the deepest parts of the Patchawarra Trough and over the Moomba high on the margin of the Nappamerri Trough are targets for deep CSG. Gas desorption analysis of a thick Patchawarra coal seam returned excellent total raw gas results averaging 21.2 scc/g (680 scf/ton) across 10 m. Scanning electron microscopy has shown that the coals contain significant microporosity.

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2

Ahmad, Maqsood, Ali Hussain, Reuben Koo, Hoang Nguyen's, and Manouchehr Haghighi. "Evaluation of free porosity in shale gas reservoirs (Roseneath and Murteree formations case study)." APPEA Journal 52, no. 1 (2012): 603. http://dx.doi.org/10.1071/aj11049.

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Organically rich shale rocks represent a voluminous, long-term, global source of natural gas and could be referred to as shale gas. Unlike conventional gas reservoirs, shale gas reservoirs have very low effective porosity and permeability. Therefore, an evaluation of porosity in such a tight rock is a challenge. The Roseneath and Murtree shale formations in the Cooper Basin are believed to be potential shale gas reservoirs in SA. Core samples of Murteree and Roseneath carbonaceous shales from the Della–4 and Moomba–46 wells were collected to measure interstitial and intergranular porosity in these prospective shale gas reservoirs in the Nappamerri Trough. After initial preparation, the shale core samples were investigated to determine the pore size classification and effective free porosity using the mercury injection capillary pressure technique (MCIP). The focused ion beam/scanning electron microscopy (FIB/SEM) technique was then employed to obtain micro and nano scale images of the core samples. Then, helium porosimetry was used on the samples to measure their effective porosity. Finally, the pyknometry method was used on the crushed samples to measure their total intergranular porosity. MICP techniques revealed that the samples were mainly comprised of meso-porosity, with the pore throat diameters between 2–50 nanometres and an effective porosity of less than 2%. Helium porosimetry also showed an average porosity of less than 2%. Liquid pyknometry revealed an average absolute porosity of 30.5% for Murteree shale and 39% for the the Roseneath shale, which is much higher than the results from the MCIP technique and helium porosimetry. This is an indication of having very high isolated porosity and very low permeability. The findings were analysed and validated by the use of SEM images, displaying high amounts of isolated porosity, confirming the high porosity measurement from the pyknometry technique. The results achieved strongly emphasised that gas prone, over-mature, carbonaceous shales have very low effective but very high total porosity. Therefore, it is envisaged that total intergranular porosity holding compressed gas in over-mature source rocks cannot be evaluated using the helium porosimetry and mercury injection techniques. The pyknometry technique supported by the SEM images is an alternative method; however, this method can only measure total, rather than effective, porosity.

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3

Trembath, Carrie, Lindsay Elliott, and Mark Pitkin. "The Nappamerri Trough, Cooper Basin unconventional plays: proving a hypothesis." APPEA Journal 52, no. 2 (2012): 662. http://dx.doi.org/10.1071/aj11076.

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Beach Energy has started exploring unconventional gas in the Nappamerri Trough, the central trough within the Cooper Basin, where the Permian section has long been regarded as the primary source for most of the conventional hydrocarbons found within the basin. This extended abstract discusses the data used to identify the unconventional play and the exploration program carried out to date. Mud weights, drill stem test (DST) pressures and log data from early exploration wells identified the Permian formations as overpressured. This with geochemical and mineralogy analyses indicated that the Roseneath and Murteree Shales had potential similar to successful shale gas plays being developed in the USA. The quartz and siderite content within both shale sections indicated sufficient brittleness for successful fracture stimulation. In addition, the Nappamerri Trough Permian section showed low permeabilities, which, when combined with overpressure, suggested a basin-centred style play within the Epsilon and Patchawarra sandstones and possibly the Toolachee Formation sandstones. During 2010–11, Beach drilled two exploration wells sited outside structural closure to test both the shale gas and basin centred gas system. Both wells have now been fracture stimulated, with very encouraging gas flows from the Roseneath to Patchawarra section. The latest geological data confirms the pre-drill potential for both gas flow from the shales and the presence and production of gas from sandstones outside structural closure, resulting in a significant shale and tight gas resource booking. Ongoing exploration and development will target a potential 300 Tcf gas in place in PEL 218.

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4

Guo, Fengtao, and Peter McCabe. "Lithofacies analysis and sequence stratigraphy of the Roseneath-Epsilon-Murteree gas plays in the Cooper Basin, South Australia." APPEA Journal 57, no. 2 (2017): 749. http://dx.doi.org/10.1071/aj16202.

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The early–middle Permian Roseneath-Epsilon-Murteree (REM) strata of the Cooper Basin, South Australia, has conventional and unconventional gas plays. To better understand the sedimentary evolution of the strata, eight key cored wells for the REM in the South Australia were selected and more than 1400 m cores have been characterised to study the lithofacies, facies associations and associated stacking patterns. Twelve lithofacies are identified and further categorised into eight facies associations: (1) open lacustrine, (2) lacustrine shoreface, (3) flood plain/interdistributary bay/channel fill, (4) fluvial channel/distributary channel, (5) crevasse channel/splay/natural levee, (6) distributary mouth bar, (7) prodelta, and (8) mire/swamp. Cyclic stacking patterns are distinguished both in cores and well logs. X-ray diffraction analysis indicates the lower and middle parts of the Murteree Shale mainly consist of claystone and are characteristic of deep water sediments. The upper Murteree Shale has a larger percentage of silt and sand, which suggests an overall regressive process. The Epsilon Formation displays three stages of deposition: (1) a lower, thin, upward-coarsening package of beach and lacustrine shoreline deposits with a continued regression from the underlying Murteree Shale; (2) a coaly, middle unit deposited by distributary channels, crevasse splays, mires and delta mouth bars; and (3) an upper unit of cyclic coarsening-upward claystone, siltstone and sandstone, deposited in shoreline environments with fluvial modifications. The Roseneath Shale resulted from transgression after deposition of the upper Epsilon Formation with a relatively rapid rise of lake level marked by transgressive lags. A final coarsening-upward sequence of shoreline deposits indicates an ending phase of regression.

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5

Jadoon, Quaid Khan, Eric M. Roberts, Bob Henderson, Thomas G. Blenkinsop, Raphael A. J. Wüst, and Cassy Mtelela. "Lithological and facies analysis of the Roseneath and Murteree shales, Cooper Basin, Australia." Journal of Natural Gas Science and Engineering 37 (January 2017): 138–68. http://dx.doi.org/10.1016/j.jngse.2016.10.047.

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6

Pearce, J. K., L. Turner, and D. Pandey. "Experimental and predicted geochemical shale-water reactions: Roseneath and Murteree shales of the Cooper Basin." International Journal of Coal Geology 187 (February 2018): 30–44. http://dx.doi.org/10.1016/j.coal.2017.12.008.

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7

Ahmad, Maqsood, Omer Iqbal, and Askury Abd Kadir. "Quantification of Organic richness through wireline logs: a case study of Roseneath shale formation, Cooper basin, Australia." IOP Conference Series: Earth and Environmental Science 88 (October 2017): 012020. http://dx.doi.org/10.1088/1755-1315/88/1/012020.

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8

Jadoon, Quaid Khan, Eric Roberts, Tom Blenkinsop, and Raphael Wust. "Organic petrography and thermal maturity of the Permian Roseneath and Murteree shales in the Cooper Basin, Australia." International Journal of Coal Geology 154-155 (January 2016): 240–56. http://dx.doi.org/10.1016/j.coal.2016.01.005.

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9

Jadoon, Quaid Khan, Eric Roberts, Thomas Blenkinsop, Raphael A. J. Wust, and Syed Anjum Shah. "Petrophysical evaluation and uncertainty analysis of Roseneath and Murteree shales reservoirs in Cooper Basin, Australia (a case study)." Journal of Petroleum Science and Engineering 147 (November 2016): 330–45. http://dx.doi.org/10.1016/j.petrol.2016.06.010.

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10

JADOON, Quaid Khan, Eric ROBERTS, Tom BLENKINSOP, Raphael A. J. WUST, and Syed Anjum SHAH. "Mineralogical modelling and petrophysical parameters in Permian gas shales from the Roseneath and Murteree formations, Cooper Basin, Australia." Petroleum Exploration and Development 43, no. 2 (April 2016): 277–84. http://dx.doi.org/10.1016/s1876-3804(16)30031-3.

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11

Hall, Lisa, Tony Hill, Liuqi Wang, Dianne Edwards, Tehani Kuske, Alison Troup, and Chris Boreham. "Unconventional gas prospectivity of the Cooper Basin." APPEA Journal 55, no. 2 (2015): 428. http://dx.doi.org/10.1071/aj14063.

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The Cooper Basin is an Upper Carboniferous–Middle Triassic intracratonic basin in northeast SA and southwest Queensland. The basin is Australia's premier onshore hydrocarbon-producing province and is nationally significant due to its provision of domestic gas for the east coast gas market. Exploration activity in the region has recently expanded with numerous explorers pursuing newly identified unconventional hydrocarbon plays. While conventional gas and oil prospects can usually be identified by 3D seismic, the definition and extent of the undiscovered unconventional gas resources in the basin remain poorly understood. This extended abstract reviews the hydrocarbon prospectivity of the Cooper Basin with a focus on unconventional gas resources. Regional basin architecture, characterised through source rock distribution and quality, demonstrates the abundance of viable source rocks across the basin. Petroleum system modelling, incorporating new compositional kinetics, source quality and total organic carbon (TOC) map, highlight the variability in burial, thermal and hydrocarbon generation histories between depocentres. The study documents the extent of a number of unconventional gas play types, including the extensive basin-centred and tight gas accumulations in the Gidgealpa Group, deep-dry coal gas associated with the Patchawarra and Toolachee formations, as well as the less extensive shale gas plays in the Murteree and Roseneath shales.

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12

Poole, Anastasia, Jennifer Badry, Gabriele Busanello, Brendon Mitchell, and David Schmidt. "Measure twice, cut once: determining Roseneath Epsilon Murteree (REM) shale gas potential with point-source, point-receiver full-azimuth acquisition." APPEA Journal 53, no. 2 (2013): 453. http://dx.doi.org/10.1071/aj12064.

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The key to the successful exploitation of shale resources, such as the REM shale gas interval in Queensland, is to obtain maximum reservoir contact by efficient drilling and hydraulic fracturing. This can be achieved by identifying areas of the reservoir already naturally fractured or where minimum effort is required for stimulation. Detection of these so-called sweet spots can be crucial for efficient reservoir development. Seismic methods can be used in shale gas reservoir characterisation studies to achieve an improved understanding of the structure, heterogeneity, and geotechnical stress regime of the reservoir and related containment, leading to identification of the desired production sweet spots and optimum placement of future wells. To achieve this, much more stringent requirements are placed on the quality and characteristics of seismic data than would be needed for a purely structural image. Innovative best-practice solutions based on experience in the basin and elsewhere were included in the survey design of the Winnie 3D seismic acquisition. The survey featured broadband acquisition with point-source vibroseis and point-receiver accelerometers. Omnidirectional and symmetrical dense sampling with appropriately long offsets provided uniform azimuthal coverage with extremely high trace density. The high-specification acquisition design was complemented with latest non-uniform noise attenuation to enable a fast-track interpretation, detection of velocity anomalies, pre-stack seismic inversion, and the extraction of seismic attributes in advanced stages of data processing.

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13

Jadoon, Quaid Khan, Eric M. Roberts, Robert A. Henderson, Thomas G. Blenkinsop, and Raphael A. J. Wust. "Mineralogical variability of the Permian Roseneath and Murteree Shales from the Cooper Basin, Australia: Implications for shale properties and hydrocarbon extraction." Journal of Petroleum Science and Engineering 165 (June 2018): 850–72. http://dx.doi.org/10.1016/j.petrol.2017.12.022.

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14

Hill, Anthony, Sandra Menpes, Guillaume Backè, Hani Khair, and Arezoo Siasitorbaty. "Shale gas prospectivity in South Australia." APPEA Journal 51, no. 2 (2011): 718. http://dx.doi.org/10.1071/aj10098.

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Potential shale gas bearing basins in SA are primarily dominated by thermogenic play types and span the Neoproterozoic to Cretaceous. Whilst companies have only recently commenced exploring for shale gas in the Permian Cooper Basin, strong gas shows have been routinely observed and recorded since exploration commenced in the basin in 1959. The regionally extensive Roseneath and Murteree shales represent the primary exploration focus and reach maximum thicknesses of 103 m and 86 m respectively with TOC values up to 9%. These shales are in the gas window in large parts of the basin, particularly in the Patchawarra and Nappamerri troughs. Outside the Cooper Basin, thick shale sequences in the Crayfish Subgroup of the Otway Basin, in particular the Upper and Lower Sawpit shales and to a lesser extent the Laira Formation, have good shale gas potential in the deeper portions of the basin. TOC averages up to 3% are recorded in these shales in the Penola Trough; maturities in the range of 1.3–1.5% have been modelled. Thick Permian marine shales of the Arckaringa Basin have excellent source rock characteristics, with TOC’s ranging 4.1–7.4% and averaging 5.2% over an interval exceeding 150 m in the Phillipson Trough; however, these Type II source rocks are not sufficiently mature for gas generation anywhere in the Arckaringa Basin. Shale gas has the potential to rival CSM in eastern Australia; its potential is now being explored in SA.

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15

Pokalai, Kunakorn, Yang Fei, Maqsood Ahmad, Manouchehr Haghighi, and Mary Gonzalez. "Design and optimisation of multi-stage hydraulic fracturing in a horizontal well in a shale gas reservoir in the Cooper Basin, South Australia." APPEA Journal 55, no. 1 (2015): 1. http://dx.doi.org/10.1071/aj14001.

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Multi-stage hydraulic fracturing in horizontal wells is a well-known technology and is a key mechanism for gas recovery from extremely low permeable shale gas reservoirs. Since Australia’s Cooper Basin has a more complex stress regime and higher temperatures when compared to US shale gas formations, the design and optimisation of this technology in the Cooper Basin has not been explored to the authors’ knowledge. The Murteree and Roseneath shale formations in the Cooper Basin are 8,500 ft in depth and have been targets for shale gas production by different oil and gas operators. Deeper zones are difficult to fracture, as fracture gradients are often above 1 psi/ft. In this study, 1D vertical mechanical earth modelling using petrophysical log data was developed. Then, the stress profile was tuned and validated using the minimum horizontal stress from a mini-frac test taken along a vertical well. A 3D hydraulic fracture simulation in a vertical well as developed as a pilot to select the best locations for horizontal drilling. The selection criteria for the best location included the stress regime, gas flow rate and fracture geometry. Then a multi-stage fracture treatment in a horizontal well was designed. A large number of cases were simulated based on different well lengths, stage spacing and the number of stages. The productivity index was selected as the objective function for the optimisation process. The best case finally was selected as the optimum multi-stage hydraulic fracturing in a horizontal well in the Cooper Basin.

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16

Pearce, J. K., T. Blach, G. Dawson, Y. Melnichenko, G. Southam, S. D. Golding, J. Bahadur, and D. Paterson. "Experimental acid and scCO2 reactions of Roseneath, Epsilon and Murteree gas shales: Opening or closing of gas accessible pores and metal release to water." ASEG Extended Abstracts 2019, no. 1 (November 11, 2019): 1–4. http://dx.doi.org/10.1080/22020586.2019.12073164.

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17

Guo, Fengtao, Peter McCabe, Zhiqiang Feng, Changwu Wu, Xueyan Lyu, Weilong Peng, and Jinrui Guo. "Core-based sedimentological and sequence stratigraphic analysis of shale-dominated gas plays: An example of the early to middle permian Roseneath-Epsilon-Murteree strata in the Cooper basin, Australia." Marine and Petroleum Geology 129 (July 2021): 105070. http://dx.doi.org/10.1016/j.marpetgeo.2021.105070.

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18

Iqbal, Omer, Maqsood Ahmad, and Askury abd Kadir. "Effective evaluation of shale gas reservoirs by means of an integrated approach to petrophysics and geomechanics for the optimization of hydraulic fracturing: A case study of the Permian Roseneath and Murteree Shale Gas reservoirs, Cooper Basin, Australia." Journal of Natural Gas Science and Engineering 58 (October 2018): 34–58. http://dx.doi.org/10.1016/j.jngse.2018.07.017.

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19

Backé, Guillaume, Hani Abul Khair, Rosalind King, and Simon Holford. "Fracture mapping and modelling in shale-gas target in the Cooper Basin, South Australia." APPEA Journal 51, no. 1 (2011): 397. http://dx.doi.org/10.1071/aj10025.

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The success story of a shale-gas reserve development in the United States is triggering a strong industry focus towards similar plays in Australia. The Cooper Basin (located at the border of South Australia and Queensland) and the Otway Basin (extending both onshore and offshore South Australia and Victoria) could be prime targets to develop shale-gas projects. The Cooper Basin, a late-Carboniferous to mid-Triassic basin, is the largest onshore sedimentary basin producing oil and gas from tight conventional reservoirs with low permeability. Fracture stimulation programs are used extensively to produce the oil and gas. Furthermore, new exploration strategies are now targeting possible commercial gas hosted in low-permeability Permian shale units. To maximise production, the development of shale-gas prospects requires a good understanding of the: 1. structure of the reservoirs; 2. mechanical properties of the stratigraphy; 3. fracture geometry and density; 4. in-situ stress field; and, 5. fracture stimulation strategies. In this study, we use a combination of seismic mapping techniques–including horizon and attribute mapping, and an analysis of wellbore geophysical logs–to best constrain the existing fracture network in the basins. This study is based on the processing and analysis of a 3D seismic cube–the Moomba Big Lake survey–which is located in the southwestern part of the Cooper Basin. This dataset covers an area encompassing both a structurally complex setting in the vicinity of a major fault to the SE of the survey, and an area of more subtle deformation corresponding to the southernmost part of the Nappamerri Trough. Structural fabrics trending ˜NW–SE and NE–SW, which are not visible on the amplitude seismic data, are revealed by the analysis of the seismic attributes–namely a similarity (equivalent to a coherency cube), dip steering and maximum curvature attributes. These orientations are similar to those of natural fractures mapped from borehole images logs, and can therefore be interpreted as imaging natural fractures across the Moomba-Big Lake area. This study is the first of its kind able to detect possible fractures from seismic data in the Cooper Basin. The methodology developed here can offer new insights into the structure of sedimentary basins and provide crucial parameters for the development of tight reservoirs. In parallel, a tentative forward model of the generation of a fracture network following a restoration of the Top Roseneath horizon was carried out. The relatively good correlation between the fracture orientations generated by the model and the fractures mapped from geophysical data shows that fractures in the Moomba-Big Lake area may have formed during either a N–S compressive principal horizontal stress, or an E–W compressive principal horizontal tectonic stress regime. In addition, the orientations of the fracture interpreted through this study are also compatible with a generation under the present day stress regime described in this part of the basin, with an maximal horizontal stress trending E–W.

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20

Yan Gu and Richard Fujimoto. "Performance Evaluation of the ROSENET Network Emulation System." SIMULATION 85, no. 5 (May 2009): 319–33. http://dx.doi.org/10.1177/0037549709103072.

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21

Lee, H. Y., and M. J. Ahn. "The convergence of the fully discrete solution for the Roseneau equation." Computers & Mathematics with Applications 32, no. 3 (August 1996): 15–22. http://dx.doi.org/10.1016/0898-1221(96)00110-1.

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22

Kim, Y. D., and H. Y. Lee. "The convergence of finite element Galerkin solution for the Roseneau equation." Korean Journal of Computational & Applied Mathematics 5, no. 1 (January 1998): 171–80. http://dx.doi.org/10.1007/bf03008946.

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23

Hassan-Harrirou, Hussein, Ce Zhang, and Thomas Lemmin. "RosENet: Improving Binding Affinity Prediction by Leveraging Molecular Mechanics Energies with an Ensemble of 3D Convolutional Neural Networks." Journal of Chemical Information and Modeling 60, no. 6 (May 11, 2020): 2791–802. http://dx.doi.org/10.1021/acs.jcim.0c00075.

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24

Torres, Sandra. "Social exclusion in old age: domain-specific contributions to a debate." International Journal of Ageing and Later Life 12, no. 2 (March 13, 2019): 7–24. http://dx.doi.org/10.3384/ijal.1652-8670.181227.

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Finding a suitable way to write an introduction to a Special Issue would seem to be a relatively easy task – at first glance. But when the Special Issue is dealing with a notion that is in the very midst of receiving momentum, the question arises of how one should begin, because although some potential readers may be acquainted with the topic at hand, others may have yet to understand that the topic is now in the process of conquering intellectual space. This Special Issue happens to be about such a topic. The topic of social exclusion in old age does not yet seem to be on the radar of North American scholars, for example, but has certainly become a topic to reckon with in Europe. Understanding how “the no tion of social exclusion has found its way into the lexicon of all major global governance institutions” (O’Brien & Penna 2008: 1) is what this introduction is all about. This Special Issue was, after all, first conceived as part of the series of special issues that the COST-action known as ROSENet (an acronym that stands for Reducing Old Age Social Exclusion: Collaborations in Research and Policy; www.rosenet.com) would put together to raise awareness about old-age social exclusion – a phenomenon that deserves attention as populations around the world grow older and live longer….

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25

Waldegrave, Charles, and Chris Phillipson. "Social Exclusion and Material Disadvantage: Housing, Poverty, and Living Standards Impacts." Innovation in Aging 4, Supplement_1 (December 1, 2020): 712. http://dx.doi.org/10.1093/geroni/igaa057.2506.

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Abstract SRPP 2020 Ollie Randall Symposium Award Winner. Many of the detrimental effects of material disadvantage on the lives of citizens have been well understood by public health and social scientists, and post-World War II social protection polices were designed to mitigate the negative impacts of them. As the numbers of older people increase proportionally to the rest of the population in most countries, less is known about the exclusionary impacts of material disadvantage and the roles housing, poverty and living standards play on the health, well-being and social connections of their lives. This symposium draws together research emanating out of four countries Norway, Poland, Ireland and New Zealand that are part of the European COST Action 15122 Reducing Old-Age Social Exclusion: Collaborations in Research and Policy (ROSEnet). The papers present contemporary results of specific health well-being and social impacts of material disadvantage in the four quite different countries and assesses them through the lens of social exclusion. As the growing international evidence during the last decade has highlighted the negative health and well-being impacts of loneliness and social disconnection (Holt-Lunstad et. al. 2015), the role of housing, poverty and living standards has in creating social exclusion is less well known. This research analyses the subjective and objective experiences of material disadvantage and quantifies their exclusionary impacts on well-being (e.g. quality of life, loneliness), health functioning (mental and physical) and their challenges to macro-structures (e.g. government policies, social protection).

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26

Rashedi, Kamal. "A spectral method based on Bernstein orthonormal basis functions for solving an inverse Roseneau equation." Computational and Applied Mathematics 41, no. 5 (June 18, 2022). http://dx.doi.org/10.1007/s40314-022-01908-0.

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27

Sazzad, Sadia, Aditya Rajbongshi, Rashiduzzaman Shakil, Bonna Akter, and M. Shamim Kaiser. "RoseNet: Rose leave.dataset for the development of an automation system to recognize the diseases of rose." Data in Brief, August 2022, 108497. http://dx.doi.org/10.1016/j.dib.2022.108497.

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