Well log data analysis and interpretation on the pre-Carboniferous succession in Waukarlycarly 1, Canning Basin, Western Australia

Wang, L.; Edwards, Dianne; Bailey, Alan M.; Carr, Lidena; Boreham, C.J.; Grosjean, Emmanuelle; Anderson, Jeffrey A.; Jarrett, Amber J. M.; MacFarlane, S.; Southby, Chris; Khider, Kamal; Palu, Tehani; Henson, Paul; Carson, Chris

doi:10.11636/record.2021.003

Cited by 3 publications

(11 citation statements)

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“…For the organic-rich shales, the average and maximum total density porosity are 3.43 and 5.29%, respectively, and the average and minimum water saturation are 92.8 and 49.5%, respectively. In addition, the high present day TOC content implies the probability of high adsorbed gas content (Wang et al 2023b). The petrophysical interpretation highlights that the organic-rich Fraynes Formation shales have several characteristics that may imply favourable shale gas resource prospectivity, particularly considering both free and adsorbed gas content.…”

Section: Total Density Porosity Of Shalementioning

confidence: 95%

“…In a shale reservoir, organic matter behaves like porosity to logged bulk density. The interpretation of total density porosity for the organic-rich shales was conducted by removing the kerogen effect (Wang et al 2023a(Wang et al , 2023b. Organic matter has abundant pores, which are significant for the storage capacity of adsorbed gas in shales.…”

Section: Total Density Porosity Of Shalementioning

confidence: 99%

“…Organic matter has abundant pores, which are significant for the storage capacity of adsorbed gas in shales. The organic porosity of the Fraynes Formation shales was estimated using the mass balance model (Peters et al 2005;Wang et al 2023b), and assuming the kerogen type is the mix of 50-50% Type I-II. The total water saturation was updated with the re-interpreted porosity and considering the influence of organic matter on resistivity logs (Wang et al 2023b).…”

Section: Total Density Porosity Of Shalementioning

confidence: 99%

“…The organic porosity of the Fraynes Formation shales was estimated using the mass balance model (Peters et al 2005;Wang et al 2023b), and assuming the kerogen type is the mix of 50-50% Type I-II. The total water saturation was updated with the re-interpreted porosity and considering the influence of organic matter on resistivity logs (Wang et al 2023b). The total porosity (PHITT) combines the neutrondensity porosity (PHIT_ND) for non-organic-rich rocks and total density porosity for organic-rich shales (Fig.…”

Section: Total Density Porosity Of Shalementioning

confidence: 99%

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Unconventional hydrocarbon prospectivity of the Paleoproterozoic Fraynes Formation in Manbulloo S1, Northern Territory

Wang,

Bailey,

Grosjean

et al. 2024

Aust. Energ. Prod. J.

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The Paleoproterozoic Fraynes Formation in the Birrindudu Basin is a chronostratigraphic equivalent to the prospective Barney Creek Formation in the McArthur Basin and yet a comparable understanding of its source potential is lacking. As part of Geoscience Australia’s Exploring for the Future program, this study aims to assess the hydrocarbon generating potential and shale gas prospectivity of the Fraynes Formation in the exploration drill hole Manbulloo S1 through the reconstruction of the original source-rock characteristics and well log interpretation. Internal units inside the Fraynes Formation were defined according to sedimentary facies. The hydrocarbon generation potential was estimated from the calculated original total organic carbon content, hydrogen index and thermal maturity data measured from bitumen reflectance data. The shale total porosity was re-interpreted from bulk density logs by removing the organic matter effect, adding organic porosity for the organic-rich shales, and updating the water saturation. The maximum amount of gas generated from the organic-rich source rocks is 3969, 2769 and 1912 Mcf/a-ft assuming the kerogen compositions of 100% Type I, mix of 50–50% Type I and II, and 100% Type II, respectively. The richness of organic matter and interpreted water saturation (<100%) imply favourable shale gas prospectivity in the Fraynes Formation. This work expands our knowledge on the potential unconventional energy resources in the west of the greater McArthur Basin.

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Section: Total Density Porosity Of Shalementioning

confidence: 95%

Section: Total Density Porosity Of Shalementioning

confidence: 99%

Section: Total Density Porosity Of Shalementioning

confidence: 99%

Section: Total Density Porosity Of Shalementioning

confidence: 99%

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Unconventional hydrocarbon prospectivity of the Paleoproterozoic Fraynes Formation in Manbulloo S1, Northern Territory

Wang,

Bailey,

Grosjean

et al. 2024

Aust. Energ. Prod. J.

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“…Wireline logging was undertaken and pre-processed by Weatherford Logging, including spectral gamma ray (concentrations of potassium (GRPON,%), thorium (GRTHN, ppm) and uranium (GRURN, ppm)), compressional wave slowness (DTCN, µs/ft), bulk density (DENNN, g/cm3), limestone neutron porosity (NPRLNC, m3/m3), photoelectric factor (PDPEN, b/e), shear wave slowness (DTSXXN, µs/ft), Stoneley wave slowness (DTDTXN, µs/ft), spontaneous potential (SPCGN, mv), deep (RTAFN, ohmm) and shallow resistivity (FEFEN, ohmm) logs, array induction resistivity and micro-imager logs (Geoscience Australia 2021). This study integrated conventional wireline logs, laboratory measurements, density and neutron-density crossplot interpretation results (Wang et al 2023) with the aim of approximating the petrophysical properties using artificial neural network techniques.…”

Section: Introductionmentioning

confidence: 99%

Petrophysical interpretation and reservoir characterisation on Proterozoic shales in National Drilling Initiative Carrara 1, Northern Territory

et al. 2023

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The Proterozoic succession in the National Drilling Initiative Carrara 1 drill hole, Northern Territory, is dominated by tight shales, siltstones and calcareous clastic rocks. As part of Geoscience Australia’s Exploring for the Future program, this study aimed to improve the Proterozoic shale gas reservoir characterisation by derivation of porosity, permeability and gas content from laboratory testing and machine learning approaches to wireline log interpretation. The Proterozoic Lawn Hill Formation is divided into four chemostratigraphic packages. The middle two packages are further divided into seven internal units according to principal component analysis and self-organising map clustering on well logs and inorganic geochemical properties. Artificial neural networks were then applied to interpret the mineral compositions, porosity and permeability from well logs, density and neutron-density crossplot interpretations. Gas content was estimated from the interpreted porosity, gas saturation, total organic carbon and clay contents. Petrophysical interpretation results are summarised for all chemostratigraphic packages and units. P2 (1126.3–1430.1 m) has the highest potential among the four chemostratigraphic packages. P2U1 (1126.3–1271 m) and P2U3 (1335.5–1430.1 m) units have the most favourable petrophysical properties for organic-rich shales, with average total gas contents of 1.213 and 1.315 cm3/g, geometric mean permeability of 6.6 and 25.31 µD and net shale thickness of 53.5 and 83.3 m, respectively. P3U4 (687.9–697.9 m) has high gas content and permeability, with a net shale thickness of 35.9 m. The tight non-organic-rich siltstone and shale reservoirs in package P1 (below 1430.1 m) have an average gas saturation of 17.4% and a geometric mean permeability of 0.48 µD.

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Exploring for the Future: new geomechanical data in frontier Australian basins

Bailey,

Dewhurst,

Wang

et al. 2024

Aust. Energ. Prod. J.

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Led by Geoscience Australia, Exploring for the Future (EFTF) is a A$225 million Australian Government program dedicated to exploring Australia’s resource potential and boosting investment. The EFTF program energy component aimed to attract industry investment by delivering a suite of new precompetitive geoscience data in prospective Australian sedimentary basins. Through EFTF, Geoscience Australia has acquired significant amounts of new geomechanical data from underexplored onshore sedimentary basins with identified hydrocarbon prospectivity, from both legacy and newly acquired samples. These data were acquired to build a better understanding of basin sediment rock properties, particularly looking at the reservoir and seal potential of postulated unconventional and conventional targets. Four major datasets are presented herein, representing prospective intervals from the Paleozoic Canning Basin of Western Australia, the Neoproterozoic-Paleozoic Officer Basin of South Australia and Western Australia, the Paleo-Mesoproterozoic South Nicholson region of the Northern Territory and northwest Queensland, and the Paleo-Mesoproterozoic Birrindudu Basin of the Northern Territory and Western Australia. Additionally, the Paleo-Mesoproterozoic McArthur Basin of the Northern Territory is represented by a small number of analyses. Tests include unconfined compressive strength tests, laboratory ultrasonic measurements, single and multi-stage triaxial tests and Brazilian tensile strength tests. These datasets are a precompetitive resource that can facilitate investment decisions in frontier regions, helping to identify elements of conventional and unconventional hydrocarbon systems as well as providing essential data to assess geological storage opportunities.

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Well log data analysis and interpretation on the pre-Carboniferous succession in Waukarlycarly 1, Canning Basin, Western Australia

Cited by 3 publications

References 0 publications

Unconventional hydrocarbon prospectivity of the Paleoproterozoic Fraynes Formation in Manbulloo S1, Northern Territory

Unconventional hydrocarbon prospectivity of the Paleoproterozoic Fraynes Formation in Manbulloo S1, Northern Territory

Petrophysical interpretation and reservoir characterisation on Proterozoic shales in National Drilling Initiative Carrara 1, Northern Territory

Exploring for the Future: new geomechanical data in frontier Australian basins

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