Perth Basin Research Articles

A greedy sensor selection algorithm for hyperparameterized linear Bayesian inverse problems with correlated noise models

We consider optimal sensor placement for a family of linear Bayesian inverse problems characterized by a deterministic hyper-parameter. The hyper-parameter describes distinct configurations in which measurements can be taken of the observed physical system. To optimally reduce the uncertainty in the system's model with a single set of sensors, the initial sensor placement needs to account for the non-linear state changes of all admissible configurations. We address this requirement through an observability coefficient which links the posteriors' uncertainties directly to the choice of sensors. We propose a greedy sensor selection algorithm to iteratively improve the observability coefficient for all configurations through orthogonal matching pursuit. The algorithm allows explicitly correlated noise models even for large sets of candidate sensors, and remains computationally efficient for high-dimensional forward models through model order reduction. We demonstrate our approach on a large-scale geophysical model of the Perth Basin, and provide numerical studies regarding optimality and scalability with regard to classic optimal experimental design utility functions.

Exploring natural hydrogen hotspots: a review and soil-gas survey design for identifying seepage

Exploration for natural hydrogen seepages has grown rapidly, with surface seepages being seen as a primary indication of an underlying resource. While soil gas sampling has proven successful in detecting hydrogen in the soil, current understanding of hydrogen in the subsurface remains incomplete, with various potential sources of origin. This paper presents a selected review of published hydrogen hotspots around the world, examining their distribution with respect to two main features commonly associated with natural seepages: sub-circular depressions (SCD) and fault zones. Based on the findings, the paper proposes a conceptual soil-gas survey design for efficiently identifying potential hydrogen hotspots. The proposed scheme is tested on a SCD and a fault zone located in Western Australia. The study findings near the Perth Basin and the Yilgarn Craton highlight the presence of anthropogenic artifacts in hydrogen measurement, necessitating further investigation to constrain the possible sources of hydrogen generation. The study of the SCD in the Perth Basin supports the development of a statistical understanding of hydrogen distribution around surface features associated with hydrogen hotspots. Such a framework can guide soil-gas surveys and target areas with a higher likelihood of detecting natural hydrogen seepage. By addressing these points, prospective areas for natural hydrogen seepage can be better identified and evaluated, ultimately contributing to the development of hydrogen as a sustainable energy resource. Thematic collection: This article is part of the Hydrogen as a future energy source collection available at: https://www.lyellcollection.org/topic/collections/hydrogen

Petrophysical log-driven kerogen typing: unveiling the potential of hybrid machine learning

The importance of characterizing kerogen type in evaluating source rock and the nature of hydrocarbon yield is emphasized. However, traditional laboratory geochemical assessments can be time-intensive and costly. In this study, an innovative approach was taken to bridge this gap by utilizing machine learning techniques to ascertain key parameters—Organic Oxygen Index (OI), Hydrogen Index (HI), and kerogen type—from petrophysical logs of a well in the Perth Basin, Western Australia. This approach assembled geochemical data from 138 cutting samples of the Kockatea and Woodada formations and petrophysical log data. Subsequently, six machine learning algorithms were applied to predict the OI and HI parameters. The efficacy of these methods was assessed using statistical parameters, including Coefficient of Determination (R2), Average Percentage Relative Error, Average Absolute Percentage Relative Error, Root Mean Square Error, and Standard Deviation. The Support Vector Machines method emerged as the standout performer, with an R2 of 0.993 for the OI and 0.989 for the HI, establishing itself as an optimal tool for predicting these indices. Additionally, six classifiers were employed to determine kerogen types, with accuracy tested using precision, recall, F1-Score, and accuracy parameters.The study's findings highlight the superiority of the Gradient Boosting method in kerogen-type classification, achieving an impressive accuracy rate of 93.54%. It is concluded that when utilized with petrophysical logs, machine learning methodologies offer a powerful, efficient, and cost-effective alternative for determining OI, HI, and kerogen type. The novelty of this approach lies in its ability to accurately predict these crucial parameters using readily available well-log data, potentially revolutionizing traditional geochemical analysis practices.Graphical abstract

Development and production review 2022

The Petroleum Exploration Society of Australia (PESA) Year in Review Development and Production review looks back at the oil and gas production and development activities in Australia in 2022, with a look at both the historical context of these activities, and the future implications. With the invasion of Ukraine, increasing inflationary pressures, supply chain problems, the prospect of a global recession looming, the impact of COVID-19 still lingering, and increased activism around climate change issues, sentiment was subdued for most of the year, yet there were still several highlights and events. Liquefied natural gas (LNG) production again hit record high levels although, as expected, Australia lost its position as the top LNG exporting country in the world to the USA. The development of the Scarborough/Pluto 2 LNG project continued, as did the Barossa project, although the latter hit legal and approval hurdles resulting in suspension of drilling activities (which are not expected to impact the overall schedule). Final investment decisions were taken on the further development of the Kipper field in the Gippsland Basin, the Crux project in the Browse Basin and the Walyering project in the Perth Basin. The domestic markets continue to have unique issues with major concerns about gas supply in the East co-existing with stalled developments and falling supply in the Northern Territory in stark contrast to the West, where there is significant development and take-over activity.

The other Erregulla discovery, Wagina Sandstone, north Perth Basin

Although the major focus of exploration within the onshore north Perth Basin and the greater Erregulla area has been the prolific high gas-rate Kingia discoveries, there are additional discoveries being made in sandstones within basal parts of the upper Permian Wagina Sandstone. During the drilling of the most recent of these discoveries at South Erregulla-1, a high-pressure porous interval was encountered within the lower part of the Wagina Sandstone at a depth of 3903 m. The Wagina Sandstone has been enigmatic in the deeper Dandaragan Trough. To date, 10 wells in the Dandaragan Trough have penetrated the entire upper Permian sequence, and all wells show some gas charge. However, nine of the 10 wells contain only minor amounts of mostly low-quality reservoir development. Only the South Erregulla-1 well contains conventional porosity as well as significant amounts of tight gas pay. The mechanism for preserving porosity in the basal Wagina sandstone is different to the early Permian Kingia Sandstone but provides an important and additional gas reservoir in the deepest Wagina penetration in the Perth Basin.

Exploration and appraisal year in review 2022

Petroleum exploration activity in Australia decreased in 2022. The total number of exploration wells drilled and expenditure across Federal offshore and state jurisdictions decreased from 2021 levels. The number of exploration permits awarded and acreage made available for exploration was also lower than that of 2021. However, more appraisal wells were drilled in 2022. Onshore exploration expenditure in Australia has exceeded that of the offshore since 2019 and remains the focus of exploration activity. Exploration activity and expenditure has not followed the increase in oil and gas prices of recent years, suggesting external factors are suppressing and impeding exploration activity. Twenty-six exploration wells were drilled in the year compared to 29 in the previous year, resulting in one offshore and eight onshore petroleum discoveries. The Pavo oil discovery in the Bedout Sub-basin and in the same exploration play as the Dorado oil discovery of 2018, was the only offshore discovery in 2022. Onshore exploration ‘hot-spots’ include the Northern Perth Basin and the Cooper–Eromanga Basin. The Permian Kingia Sandstone play of the Northern Perth Basin yielded the South Erregulla and Gynatrix gas discoveries, and the Jurassic Namur Sandstone play of the Cooper – Eromanga ‘Western Flank’ was extended yielding the Bangalee-1, Coorong-1, Magic Beach-1 and Rocky-1 oil discoveries.

Tech Talk: Petroleum Geology & Geochemistry of West Australian Source Rocks, an Overview

Source rocks, crude oil and natural gas data from the sedimentary basins within the Western Australia state jurisdiction, namely Amadeus, Bight, Bonaparte, Browse, Canning, Carnarvon, Officer, and Perth basins identified several formations with petroleum source potential. Some of these source rocks have sourced significant discovered volumes of petroleum resources accumulated within sand, carbonate, and shale reservoirs of Western Australia.

Implementing SRMS in the North Perth Basin: challenges and practical solutions

The Society of Petroleum Engineers (SPE) published the CO2 Storage Resources Management System (SRMS) in 2017 to provide a CO2 Storage Resource classification. Guidelines for its application were published in July 2022. In this paper, Molyneux Advisors (MA) has used these principles to classify and categorise potential CO2 storage resources of Deep Saline Formations (DSFs) and Depleted Oil & Gas Accumulations (DOGAs) in the North Perth Basin (NPB). A subsurface inter-disciplinary approach was taken, integrating supporting data and interpretations in calculating storage volumes. Key challenges exist in: classification of storage resources for four DSFs which jointly constitute more than 90% of potential CO2 storage resources in the NPB; quantifying accessible and Inaccessible Storage Resource volumes; and determining the low-, base- and high-case estimates based upon the uncertainty ranges of inputs. Furthermore, approval of any CO2 storage development is yet to be granted by the Western Australian State Government.

Geological Survey of Western Australia: Western Officer and Perth Basins SEEBASE reports

Geological Survey of Western Australia: Western Officer and Perth Basins SEEBASE reports

The potential extent of Early Triassic Kockatea Shale equivalent source rocks in the Northern Carnarvon and Perth Basins, Western Australia

In the northern Perth Basin (Western Australia), the Early Triassic Kockatea Shale is the primary petroleum source rock. Possible source rocks in the Northern Carnarvon Basin are more varied and include the Upper Jurassic Dingo Claystone as well as the Early Triassic Locker Shale. Biomarker analyses were conducted on petroleum samples from these basins to understand the nature of the petroleum systems. Many of the analysed petroleum samples contain carotenoids (okenane, chlorobactane and isorenieratane) derived from photosynthetic sulfur bacteria, suggesting that their source rocks were deposited under conditions of photic zone euxinia (PZE) and/or derived from microbialites. In the northern Perth Basin, the major lithofacies contributing to the source rock are dark coloured mudstones deposited under PZE conditions and/or derived from microbialites. In the southern Perth Basin, the potential source rock is either Permian, Jurassic or Cretaceous in age as indicated by the low concentrations or absence of carotenoids and the Triassic biomarker n -C 33 alkylcyclohexane. There is also a possibility that the Lower Triassic Locker Shale is the source rock of petroleum in the Tubridgi field on the Peedamullah Shelf of the Northern Carnarvon Basin, based on the similarity of biomarkers to Perth Basin petroleum sourced from the Kockatea Shale. However, the possibility of charge from the Upper Jurassic Dingo Claystone cannot be entirely excluded. Supplementary material: biomarker dataset is available at https://doi.org/10.6084/m9.figshare.c.6452153

Early Permian zircon ages from the P. confluens and P. pseudoreticulata spore-pollen zones in the southern Bonaparte and Canning basins, Northwestern Australia

The Pseudoreticulatispora confluens–P. pseudoreticulata spore-pollen zonal datum typically coincides with the end of widespread Permian glacial deposits in Western Australia. Although previously attributed to the mid-Sakmarian, chemical abrasion isotope dilution thermal ionisation mass spectrometry (TIMS) dating of zircons from volcanic tuffs in the Ditji Formation of the Bonaparte Basin and the Grant Group in the Canning Basin point to an Asselian age of about 295.25 Ma for this datum. All dated zircons from the Ditji Formation came from petroleum well cuttings but the accompanying palynology was mostly from sidewall cores; however, all Grant Group samples were from conventional core. TIMS dates from the Ditji Formation range in age from 295.2 to 292.7 Ma whereas the only productive tuff from the Grant Group yielded a 296.26 Ma date. By comparison, there are no zircon dates to constrain the onset of glacial deposition in Australia. The Bonaparte Basin ages overlap with those for the Edie Tuff (296.1–294.5 Ma) in Queensland’s Galilee Basin, approximately 2000 km to the southeast, which also lies close to the base of the P. pseudoreticulata Zone. To date the only fossil group within the P. confluens Zone in Western Australia to provide independent age control, albeit loosely, are goniatites from the northern Perth Basin (Uraloceras irwinense and Juresanites jacksoni) that have consistently been attributed to the Sakmarian; these require a reassessment of their affinity with Russian faunas and therefore to global stratotypes. The position of the Carboniferous–Permian boundary is elusive in Australia and will remain so until additional volcanic tuffs containing young datable zircons are found; however, spore-pollen and zircon dates from Namibia place this boundary within the P. confluens Zone.

Valanginian–Hauterivian vegetation inferred from palynological successions from the southern Perth Basin, Western Australia

The stepwise fragmentation of Gondwana had a lasting impact on Southern Hemisphere ecosystems, but its consequences remain difficult to ascertain without detailed knowledge of the biota colonizing the supercontinent before and during breakup. This palynological study characterizes the Early Cretaceous vegetation of the southern Perth Basin, a key location during the separation of Greater India from Western Australia. The well-preserved palynological assemblages recorded here include marine and putative freshwater dinoflagellate cysts and diverse spore and pollen associations. The palynomorphs indicate lacustrine, fluvial and estuarine depositional settings in the southern Perth Basin between the Berriasian and Hauterivian. The estuarine assemblages are characterized by rare to common marine dinoflagellate cysts, which indicate the early stages of marine deposition, conditions that later prevailed across most of the basin. The Early Cretaceous vegetation of the study area, as inferred from spores and pollen, is interpreted to consist mainly of conifer forests dominated by Araucariaceae, Podocarpaceae and Cheirolepidiaceae with an understory of ferns (Osmundaceae, Schizaeaceae) and other spore-producers (clubmosses, mosses, liverworts and hornworts). Two vegetation-types are hypothesized for the region with their distribution related to substrate characteristics and water availability: a more mesic, structurally complex, riverine forest within paleovalleys and topographic lows, and a more open forest accross the hinterland.

Estimation of density log and sonic log using artificial intelligence: an example from the Perth Basin, Australia

It is well understood that with a large number of data, an excellent interpretation of the subsurface condition can be produced, and also our understandings of the subsurface conditions can be improved significantly. However, having abundant subsurface geological and petrophysical data sometimes may not be possible, mainly due to budget issues. This situation can generate issues during hydrocarbon exploration and/or development activities.
 In this paper, the authors tried to apply artificial intelligence (AI) techniques to estimate outcomes values of particular wireline log data, using available petrophysic data. Two types of AI were selected and these are artificial neural network (ANN), and multiple linear regression (MLR). This research aims to advance our understanding of AI and its application in geology. There are three objectives of this study: (1) to estimate sonic log (DT) and density log (RhoB) using different types of AI (ANN and MLR); (2) to assess the best AI technique that can be used to estimate certain wireline log data; and (3) to compare the estimated wireline log values with the real, recorded values from the subsurface.
 Findings from this study show that ANN consistently provided a better accuracy percentage compared to MLR when estimating density log (RhoB). While using different set of data and technique, estimation of sonic log (DT) produced different accuracy level. Moreover, crossplot validation of the results show that the results from ANN analysis produced higher trendline reliability (R2) and correlation coefficient (R) than the results from MLR analysis. Comparison of the estimated RhoB and DT log data with the original recorded data shows minor mismatch. This is evident that AI technique can be a reliable solution to estimate particular outcomes of wireline log data, due to limited availability of the original recorded subsurface petrophysic data. It is expected that these findings would provide new insights into the application of AI in geology, and encourage the readers to explore and expand the many possibilities of the application of AI in geology.

Paleogeographic Reconstruction of the Paleozoic Lhasa Terrane Through Detrital Zircon Mixing Modeling

AbstractA late Mesoproterozoic detrital zircon (DZ) age population, which was previously considered diagnostic of a link between the Lhasa terrane and northwest Australia, occurs in other Gondwanan components, thus obscuring the paleogeographic position of the Lhasa terrane in Gondwana. Here we compiled large‐n (n ≥ 300) DZ U‐Pb data from the Lhasa terrane and potential source regions in various proposed reconstructions, and attempted to synthesize the Lhasa DZ age spectra through DZ mixing modeling. Our modeling results support the Permo‐Carboniferous Lhasa terrane having received sediment from NW Australia (mainly the Perth basin) rather than India or Africa. This, in combination with stratigraphic and paleontological evidence from the northern margin of eastern Gondwana positions the Paleozoic Lhasa terrane adjacent to the boundary between Australia and India. This study suggests that the DZ mixing modeling method based on large‐n DZ data can be used effectively for constraining paleogeographic reconstruction of continents.

Tectonic and climatic controls on sediment transport to the Southeast Indian Ocean during the Eocene: New insights from IODP Site U1514

The Eocene was a critical period of global plate reorganization and it also saw the Earth's climate transition from the warmhouse state to the coolhouse state. Reconstructing the Eocene sedimentary history in the climate-sensitive Southern Ocean is important for understanding paleoenvironmental changes in response to the accelerated Australia/Antarctica separation and global cooling throughout the middle and late Eocene. Here, we present the first detailed multiproxy record of a continuous sequence from International Ocean Discovery Program (IODP) Site U1514 in the Mentelle Basin off southwestern Australia. Our aim is to reconstruct the sediment provenances and paleoenvironmental evolution in response to the abovementioned climatic and tectonic changes in the mid-high southern latitudes during the Eocene. Provenance analyses based on Sr-Nd isotopes, trace elements, and clay mineral assemblages suggest that Eocene sediments at Site U1514 predominantly originated from the southwestern Australian continent and the Naturaliste Plateau. Sediment provenance variations during the middle Eocene indicate that the onset of fast separation between Australia and Antarctica at 43 Ma caused an increased supply of volcanic materials from the Naturaliste Plateau between 43 and 38 Ma. Terrigenous inputs to the Mentelle Basin during the middle Eocene were primarily controlled by paleoclimate changes rather than tectonic processes because coeval clay mineralogical changes (higher kaolinite/smectite ratio and MARkaolinite) indicate a period of stronger physical erosion and chemical weathering on the western Australian continent that resulted in increased terrigenous materials delivered to the Mentelle Basin. Our results reveal a 5 Myr-long (43–38 Ma) warming reversal in the southern mid-high latitudes, providing an exception to the generally short-lived (10–100 kyr-long) hyperthermals that interrupted the long-term global cooling throughout the middle to late Eocene. As for the late Eocene (38–37 Ma), tectonic processes related to the sudden acceleration in seafloor spreading in the Tasman Sea led to the exposure of shallower areas, resulting in rapid detritus accumulation at the study site. During the late Eocene (37–34 Ma), major sediment provenance shifted from distal source areas (e.g., the Yilgarn Craton) to relatively proximal sources (e.g., the Leeuwin Block and Perth Basin). We interpret that the regional uplift in southwestern Australia and coeval climate cooling resulted in the diversion and inactivation of large drainage systems, thus blocking the transportation of sediment from distant regions.

Photic zone redox oscillations and microbialite development recorded by Early Triassic sediments of the Perth Basin: A geochemical approach

Photic zone euxinia (PZE) has previously been identified in the Early Triassic Kockatea Shale of the northern Perth Basin, based on the presence of biomarkers such as isorenieratane, which is derived from isorenieratene produced by green sulfur bacteria. However, green and purple sulfur bacteria can also occur in microbial mats. In this study we present a basin-scale assessment of biomarkers associated with open water column PZE and/or microbialites. The lithofacies from the Early Triassic of the northern part of the northern Perth Basin consist of dark coloured mudstones (black to dark grey) with microbialites, which were deposited away from basin margins. These samples are found to contain okenane, chlorobactane and isorenieratane derived from carotenoid pigments of purple, green-green and green–brown sulfur bacteria, respectively. These biomarkers are not observed in the light coloured mudstones (medium grey) formed under oxic conditions in a tidal environment with higher clastic input close to the basin margins in the southern part of the basin where shallow marine sandstones were also deposited. Okenane and chlorobactane were abundant in facies containing microbialites which developed in a shallow water setting on intra-basinal structural highs. The development of oxic conditions near the basin margins in the Perth Basin provided refuges for organisms during the end Permian mass extinction event. Okenane was more abundant in the microbialite facies compared with the dark coloured mudstones deposited under PZE. C33n-alkylcyclohexane (n-C33 ACH) has previously been described as a biomarker associated with ecosystem collapse during the lower Triassic, and its ratio relative to the C34n-alkane was elevated in facies that contain abundant microbialites. Mercury (Hg) to total reduced inorganic sulfur (TRIS) and Hg to total organic carbon (TOC) ratios are positively correlated, supporting the development of euxinia as sulfide sequesters Hg. The high Hg/TRIS values in microbialite facies support mat development with high Hg concentrations. The values of δ13COM and δ34S were isotopically lighter in microbialite facies when compared with mudstones formed under PZE, although samples deposited under oxic conditions showed the isotopically lightest δ13COM and isotopically heaviest δ34S. The variation in δ13COM probably reflects the different carbon fixation pathway of various sulfur bacteria, while it appears that the difference of δ34S values between PZE and microbialites is a result of differences in the microbial community structure and the higher relative abundance of purple sulfur bacteria. In addition, fluctuations between PZE and oxic conditions were identified throughout the sampled intervals attributed to fluctuations in the depth of chemocline. Under the shallower chemocline, PZE developed widely in the basin, even in shallower waters. Under the deeper chemocline PZE was absent or limited to deeper water, and oxic conditions developed in shallower water. The fluctuations of PZE and oxic conditions in the northern Perth Basin suggest the development of multiple episodes of harsh environmental conditions after the end-Permian mass extinction, similar to those identified in other regions (e.g., Meishan in China and Peace River in Canada).

A new integrated approach to resolve the saturation profile using high-resolution facies in heterogenous reservoirs

The saturation calculation in complex reservoirs remains a major challenge to the oil and gas industry. In simple formations, a tendency towards simple saturation models such as Archie or Simandoux for clean and shaly reservoirs respectively is always preferable. These models were found to be working effectively in homogeneous formations within which the porosity and permeability are linked in the light of a simple facies scheme. Where the rocks show some degrees of heterogeneity, the well-logs are usually affected by different factors. This adversely results in a compromised or averaged log profiles that may affect the saturation calculations. Four wells drilled across a shaly sand of high heterogeneity have been studied in the Perth Basin, Western Australia. The aim is to resolve the hydrocarbon saturation and explain the high productivity results, despite the high water saturation, obtained through a conducted formation well test across the interested reservoir zones. A new integration technique between a suite of conventional and advanced logging tools together with the capillary pressure measurements has been carried out to generate a high-resolution reservoir saturation profile, that is lithofacies dependent. Three different independent methods were used in the studied wells to calculate the saturation and to reduce the uncertainty of the final estimated profiles. The methods are the resistivity-based saturation, the NMR-based irreducible saturation, and a new application through saturation height modeling. Furthermore, through the workflow, an effective calibration for the magnetic resonance T2 cutoff has been applied that is supported by the excellent reservoir production behavior from such complex reservoir. The methodology will help resolve the saturation calculation as one of the most challenging reservoir parameters, particularly where the resistivity logs are affected in complicated shaly sand environments. The effectiveness of the workflow shines the possibility to predict high resolution facies and saturation profiles in the lack of resistivity logs. A further possibility can complete the analysis on real time basis, which can certainly provide facies and saturation profiles extended to the uncored wells. Application of this methodology in the uncored wells has shown very encouraging results in various well trajectories, either vertical, deviated or horizontal long boreholes.

Moisture source identification for precipitation associated with tropical cyclone development over the Indian Ocean: a Lagrangian approach

In this study, we investigated the moisture sources for precipitation through a Lagrangian approach during the genesis, intensification, and dissipation phases of all tropical cyclones (TCs) that occurred over the two hemispheric sub-basins of the Indian Ocean (IO) from 1980 to 2018. In the North IO (NIO), TCs formed and reached their maximum intensity on both sides of the Indian Peninsula, to the east in the Bay of Bengal (BoB), and to the west in the Arabian Sea (AS). The oceanic areas where TCs occurred were their main moisture sources for precipitation associated with TCs. Additionally, for TCs over the BoB, continental sources from the Ganges River basin and the South China Sea also played a notable role; for TCs over the AS, the Somali Low-Level jet (along the African coast in a northerly direction) also acted as an essential moisture transport. In the South IO (SIO), the western, central, and eastern basins were identified as the preferred areas for the genesis and development of TCs. During TC activity, the central IO and the Wharton and Perth basins mostly supplied atmospheric moisture. The Mascarene High circulation was the main moisture transport mechanism for the precipitation of TCs formed in the SIO basin. In both basins, during their intensification process, TCs gained more moisture (even more intensely when reaching the hurricane category) than during the genesis or dissipation stages. Additionally, the modulation during monsoonal seasons of the moisture contribution to the TCs was more noticeable over the NIO basin than for the SIO. Overall, the moisture uptake for precipitation from the sources for TCs occurred slightly faster in the NIO basin than in the SIO basin.

Concurrent 3. Presentation for: The impact of new supply from the Perth Basin on the supply of natural gas in Western Australia

Presented on Tuesday 17 May: Session 3 The Australian Energy Market Operator (AEMO) forecasts demand for natural gas (gas) in Western Australia will remain steady through the 2020s, but that the local production will drop below anticipated demand in the mid-2020s and again from 2030 onwards. If this situation eventuates, lack of gas production will impact the competitiveness of WA’s energy-consuming industries. This paper demonstrates that the Perth Basin has the potential to meet this supply–demand gap and augment existing sources of gas over the next 20+ years. A subsurface-led assessment of the Perth Basin’s Reserves, Contingent Resources and Prospective Resources incorporating all recent exploration well results shows that the unrisked resource potential of the Perth Basin is 7052 bcfe (7.475 PJ) with production potential up to 1100 TJ/day. The basis for these estimates will be illustrated with examples, alongside a discussion of the variables that affect the resource assessment, the impact of capacity constraints on the timing of development of Perth Basin gas, and the dynamics of the WA gas market. To access the presentation click the link on the right. To read the full paper click here

Concurrent 13. Presentation for: 2021 Development and production review

Presented on Wednesday 18 May: Session 13 The Petroleum Exploration Society of Australia (PESA) Year in Review Development and Production review looks back at the oil and gas production and development activities in Australia in 2021, with a look at both the historical context of these activities, and the future implications. With the impact of COVID-19 continuing throughout the year, and increased awareness of the impact of emissions on climate change there were several notable highlights and events for the year. Liquefied natural gas (LNG) production hit record high levels and confirmed Australia as the current top LNG exporting country in the world. Two major LNG-related projects were sanctioned: Barossa in March 2021, and Scarborough/Pluto 2 in November 2021 and the Moomba Carbon Capture and Storage project was also sanctioned in November. The domestic market looked a lot like the classic novel ‘A Tale of Two Cities’ with major concerns about gas supply in the East contrasting with significant discoveries and development in the Perth Basin in the West. To access the presentation click the link on the right. To read the full paper click here