Play-based Exploration Research Articles

CELEBRATE Feeding: A Responsive Approach to Food and Feeding in Early Learning Settings.

Early learning and child care (ELCC) settings in Canada follow nutrition standards that outline food provisions, with many also encouraging responsive feeding practices that help to create a supportive environment for children. Caregivers who lack confidence in children's ability to regulate their own intake, or those who feel stressed about mealtime, may unknowingly engage in less responsive feeding practices. The CELEBRATE Feeding Approach is a flexible framework, driven by behaviour change theory, that builds on previous definitions and concepts of responsive feeding in ELCC environments. Through this approach, there is an intentional focus on supporting early childhood educators to implement feeding practices that are more responsive. The approach incorporates 13 target educator behaviours related to the three overlapping categories of CELEBRATE language, CELEBRATE Mealtime, and CELEBRATE Play. These practices recognize and support the development of a child's sense of autonomy, confidence, and self-regulation not only at mealtimes but also through play-based exploration and language that is used throughout the day around food and feeding. The goal is that children will be open to a wide variety of food, develop their self-regulation skills, and build the foundation for a positive relationship with food throughout their lifetime.

Using Large-Size Three-Dimensional Marine Electromagnetic Data for the Efficient Combined Investigation of Natural Hydrogen and Hydrocarbon Gas Reservoirs: A Geologically Consistent and Process-Oriented Approach with Implications for Carbon Footprint Reduction

The recycling or burial of carbon dioxide in depleted petroleum reservoirs and re-imagining exploration strategies that focus on hydrogen reservoirs (with any associated hydrocarbon gas as the upside potential) are a necessity in today’s environmental and geopolitical climate. Given that geologic hydrogen and hydrocarbon gases may occur in the same or different reservoirs, there will be gains in efficiency when searching for both resources together since they share some commonalities, but there is no geophysical workflow available yet for this purpose. Three-dimensional (3D) marine controlled-source electromagnetic (CSEM) and magnetotelluric (MT) methods provide valuable information on rock-and-fluid variations in the subsurface and can be used to investigate hydrogen and hydrocarbon reservoirs, source rocks, and the migration pathways of contrasting resistivity relative to the host rock. In this paper, a process-oriented CSEM-MT workflow is proposed for the efficient combined investigation of reservoir hydrocarbon and hydrogen within a play-based exploration and production framework that emphasizes carbon footprint reduction. It has the following challenging elements: finding the right basin (and block), selecting the right prospect, drilling the right well, and exploiting the opportunities for sustainability and CO2 recycling or burial in the appropriate reservoirs. Recent methodological developments that integrate 3D CSEM-MT imaging into the appropriate structural constraints to derive the geologically robust models necessary for resolving these challenges and their extension to reservoir monitoring are described. Instructive case studies are revisited, showing how 3D CSEM-MT models facilitate the interpretation of resistivity information in terms of the key elements of geological prospect evaluation (presence of source rocks, migration and charge, reservoir rock, and trap and seal) and understanding how deep geological processes control the distribution and charging of potential hydrocarbon, geothermal, and hydrogen reservoirs. In particular, evidence is provided that deep crustal resistivity imaging can map serpentinized ultramafic rocks (possible source rocks for hydrogen) in offshore northwest Borneo and can be combined with seismic reflection data to map vertical fluid migration pathways and their barrier (or seal), as exemplified by the subhorizontal detachment zones in Eocene shale in the Mexican Ridges fold belt of the southwest of the Gulf of Mexico, raising the possibility of using integrated geophysical methods to map hydrogen kitchens in different terrains. The methodological advancements and new combined investigative workflow provide a way for improved resource mapping and monitoring and, hence, a technology that could play a critical role in helping the world reach net-zero emissions by 2050.

Underexplored but not forgotten: assessing the energy resources potential of the greater Pedirka Basin region through play-based mapping

The Pedirka, Simpson and western Eromanga basins in central Australia have had a chequered exploration history which has seen only 42 wells drilled across a study area of ~210 000 km2. Exploration initially focused on conventional hydrocarbons from the 1950s–1980s, before shifting towards coal seam gas (CSG) opportunities in the mid-2000s. Active petroleum systems have been proven in the region by a non-commercial oil discovery at Poolowanna 1 in 1977, and by several wells that showed evidence of residual oil columns. CSG exploration programs have confirmed the presence of thick, marginally mature coal intervals on the flanks of the basins, but are yet to evaluate the CSG potential of the deeper troughs. Geoscience Australia, the Northern Territory Geological Survey and the South Australian Department for Energy and Mining have been collaborating on the Australia’s Future Energy Resources project to undertake an assessment of the resource potential for conventional and unconventional hydrocarbons, and the geological storage of CO2 (GSC) potential of the greater Pedirka region. The project has applied a play-based exploration approach to qualitatively assess the resource potential of the region. The Carboniferous to Cretaceous stratigraphic interval was divided into 14 plays which were evaluated for the presence of sediment-hosted energy resources through post-drill analysis, gross depositional environment mapping and common risk segment mapping. The analysis identified energy resources and GSC potential across multiple plays and locations within the study area. These results demonstrate, that while the region is underexplored, it should not be overlooked by future exploration activities.

Concurrent 1. Presentation for: A regional chronostratigraphic framework for play-based resource assessments in the Eromanga Basin

Presented on Tuesday 17 May: Session 1 Geoscience Australia is undertaking a series of basin-scale assessments to identify the ‘yet-to-find’ resource potential for hydrocarbons, as well as for groundwater resources and carbon capture and storage (CCS) opportunities in central Australia under the Exploring for the Future (EFTF) Program. A play-based exploration approach is being used to systematically evaluate the key risk elements for each resource type through the analysis of drilling results and spatial data to map ‘sweet spots’ for exploration. These assessments aim to reduce the risks and uncertainties for explorers by providing spatially enabled assessments of energy resources and CCS potential. The work will also improve the understanding of existing groundwater resources which may be impacted by future energy resource developments or provide feedstock for future green hydrogen projects. A key requirement for undertaking such play-based resource assessments is to apply a common regional chronostratigraphic framework across all the resource types that link different geological unit nomenclatures through defining the assessed reservoir and seal intervals and their associated sequence stratigraphic surfaces (sequence boundaries, transgressive surfaces and maximum flooding surfaces). A Mesozoic chronostratigraphic framework has been developed for the Eromanga Basin, which defines nine regional play intervals that host the known hydrocarbon and groundwater resources, or represent potential CCS targets. The Mesozoic play framework is now being applied to undertake play-based low-carbon energy resource assessments in the western Eromanga Basin, with initial work focussing on the interpretation and correlation of the nine play intervals in wells for post-drill analysis. To access the presentation click the link on the right. To read the full paper click here

A regional chronostratigraphic framework for play-based resource assessments in the Eromanga Basin

Geoscience Australia is undertaking a series of basin-scale assessments to identify the ‘yet-to-find’ resource potential for hydrocarbons, as well as for groundwater resources and carbon capture and storage (CCS) opportunities in central Australia under the Exploring for the Future (EFTF) Program. A play-based exploration approach is being used to systematically evaluate the key risk elements for each resource type through the analysis of drilling results and spatial data to map ‘sweet spots’ for exploration. These assessments aim to reduce the risks and uncertainties for explorers by providing spatially enabled assessments of energy resources and CCS potential. The work will also improve the understanding of existing groundwater resources which may be impacted by future energy resource developments or provide feedstock for future green hydrogen projects. A key requirement for undertaking such play-based resource assessments is to apply a common regional chronostratigraphic framework across all the resource types that link different geological unit nomenclatures through defining the assessed reservoir and seal intervals and their associated sequence stratigraphic surfaces (sequence boundaries, transgressive surfaces and maximum flooding surfaces). A Mesozoic chronostratigraphic framework has been developed for the Eromanga Basin, which defines nine regional play intervals that host the known hydrocarbon and groundwater resources, or represent potential CCS targets. The Mesozoic play framework is now being applied to undertake play-based low-carbon energy resource assessments in the western Eromanga Basin, with initial work focussing on the interpretation and correlation of the nine play intervals in wells for post-drill analysis.

Seismic acquisition and imaging strategies for unlocking subsurface complexities in Malaysian basins

Seismic data acquisition and imaging technologies have made important contributions to hydrocarbon discoveries and enhancing recovery from existing reservoirs in Malaysian basins. PETRONAS has been leveraging these technologies to address the exploration and development challenges encountered in Malaysian basins and other parts of the world and to support its play-based exploration. Some of the key technology applications include imaging below shallow gas and carbonates, imaging of complex geology for exploring deep water and deep plays, and high-resolution imaging of shallow clastic plays. Dual and multimeasurement streamers, multiazimuth and full-azimuth seismic, triple- and penta-source blended acquisition, and two- and four-component seabed seismic technologies have been integrated with high-end processing and imaging technologies such as advanced demultiple techniques, deblending, full-waveform inversion, reverse time migration, and PS-converted wave imaging to address complex subsurface challenges. In this article, we present an overview of the evolution and application of innovative seismic acquisition and imaging technologies in Malaysian basins. Selected case histories demonstrate how these technologies have enabled explorers to unlock subsurface complexities, adding value to exploration and development activities. We share the advancements in 3D seismic survey design, marine streamer acquisition, seabed seismic acquisition, and seismic imaging technologies, and how an integrated approach helped PETRONAS address geologic challenges to enhance its exploration success.

Faster play-based exploration, Petrel Sub-basin, Australia

The Paleozoic extensional Petrel Sub-basin within the Bonaparte Basin, Australia is relatively underexplored. Historical two-dimensional seismic data and 59 exploration wells provide a substantial ...

Lunar polar water resource exploration – Examination of the lunar cold trap reservoir system model and introduction of play-based exploration (PBE) techniques

Driven by a need to find low-cost energy solutions to meet anticipated demands arising from increased robotic and human cislunar activities, the extraction and utilization of naturally occurring volatiles found on the lunar surface is an area of growing interest to both the private and public space sectors. The use of hydrogen and oxygen extracted from accumulations of water is viewed as particularly promising. Several lines of evidence point to the presence of water, possibly in the form of water ice, stored within cold trap reservoirs in the permanently shadowed regions (PSRs) of the northern and southern poles of the Moon. The type and spatial resolution of available datasets however prevent evaluation of resource potential on a scale relevant to address geological uncertainties and assess the technological and economic feasibility of water resource extraction for use by an in-space market. Surface field exploration is required to reduce investment risk; however the success of resource exploration activities will depend on the selection of appropriate exploration methods. To address this we introduce the application of play-based exploration (PBE) techniques, a resource exploration approach commonly used by the terrestrial petroleum and geothermal energy industries to direct decision making regarding high-risk ventures. Applied to the Moon this method seeks to identify locations where exploration activities are most likely to encounter an economically/commercially viable quantity of water guided by the geological concepts of delivery, trapping, and storage of water molecules within a reservoir. In this study we examine the critical geological uncertainties in the reservoir system model and provide recommendations for resource exploration approach, data collection, and analysis techniques.

Old rocks, new tricks: a reinvigorated Cooper Basin offers growth opportunity

The Cooper Basin spans north-east South Australia and south-west Queensland and is Australia’s largest integrated onshore oil and gas development. Santos and Delhi first discovered commercial gas in 1963. First oil was discovered in 1970. Since then, the Cooper Basin has become a strategically important processing and transportation hub for produced gas and liquids. Continuous investment in new technology, the use of existing infrastructure and, recently, an unrelenting drive to lower drilling and production costs has delivered a low-cost, high-margin producer for east coast domestic and liquefied natural gas (LNG) export markets. This improved operating performance has, in turn, offered Santos the opportunity to reassess ‘our backyard’. The Cooper Basin boasts many growth options, remaining and emerging. Seismic advances are providing improved imaging. Data management, the use of play-based exploration studies, innovative geoscience thinking and renewed investment risk appetite are playing key roles in the development of discovered resources and the exploration of new and emerging plays. Targeted wildcat exploration and appraisal programs, supported by low-cost operations, offer the potential to unlock significant remaining oil and gas resources. The Cooper Basin is poised for another stage of growth. This tangible potential emphasises the critical future role the basin is likely to continue to play as an onshore Australian hydrocarbon supply hub.

Play-based exploration in the southern Cooper Basin: a systematic approach to exploration in a mature basin

Exploration within a mature basin poses many challenges, not least how to best utilise resources and time to maximise success and reduce cost. Play-based exploration (PBE) provides a team-based approach to combine key aspects of the petroleum system into an integrated and wholistic view of basin prospectivity. While the PBE methodology is well established, it is not often applied to its full extent on a basin scale. After a period of declining exploration success in parts of the South Australia Cooper-Eromanga Basin, this study was undertaken by a dedicated regional geoscience team with the aim of rebuilding an understanding of the basin, based on first principles and stripping away exploration paradigms. The study area comprises an acreage position in the South Australian and Queensland Cooper-Eromanga Basins covering 70 000 km2 in which Senex Energy has 14 oil fields, has drilled more than 80 exploration wells and has acquired 2D and 3D seismic material. A plethora of proven and emerging plays exist within the acreage ranging from high productivity light sweet oil (Birkhead and Namur Reservoirs) to tight oil (Murta Formation), conventional gas (Toolachee/Epsilon and Patchawarra Formation), tight gas (Patchawarra Formation) and the emerging deep coal play (Toolachee and Patchawarra Coals). Play-based exploration methodologies incorporating the integration of seismic data, log and palynological data, structural analysis, geochemistry, 3D basin modelling, consistent well failure analysis and gross depositional environment maps have allowed the systematic creation of common risk segment maps at all play levels. This information is now actively utilised for permit management, business development, work program creation and portfolio management. This paper will present an example of the work focussing on the southern section of the South Australian Cooper-Eromanga Basin.

Exploration of the south-eastern part of the Frontier Amadeus Basin, Northern Territory, Australia

The Neoproterozoic to Late Paleozoic-aged Amadeus Basin is a large (~170 000 km2) east–west-trending basin, bounded to the south by the Musgrave Province and to the north by the Arunta Block of the Northern Territory. Commercial oil and gas production is established in the northern part of the basin but the southern part is still a frontier exploration area. Vintage and new seismic reflection data have been used with well data along the south-eastern Amadeus Basin to construct a new structural and depositional model. Three major phases of deformation controlling deposition have been identified. The first phase is characterised by a SW–NE trending structural fabric and is thought to be older than the deposition of the first sediments identified above basement (Heavitree and Bitter Springs formations). The second phase corresponds to the Petermann Orogeny (580–540 Ma) and trends in a NW–SE orientation. The third phase is the Alice Springs Orogeny (450–300 Ma) and is oriented W–E to WNW–ESE in this part of the basin. This tectono-stratigraphic model involving three distinct phases of deformation potentially explains several critical observations: the lack of Heavitree reservoir at Mt Kitty-1, limited salt movements before the Petermann Orogeny (~300 Ma after its deposition) and salt-involved structures that can be either capped by the Petermann Unconformity and overlying Cambrian to Devonian sediments, or can reach the present day surface. Finally, this model, along with availability of good quality seismic data, opens new perspectives for the hydrocarbon exploration of the Amadeus Basin. Each of the tectonic phases impacts the primary petroleum system and underpins play-based exploration.

Design of UCC and Play Based Inquiry Teaching and Learning Model

This study seeks to develop an adaptive teaching and learning mode utilizing elementary school education UCC and play-based exploration by extracting the computer science subjects from the ICT basic quality curriculum and based on literature review on problem solving learning model, play and UCC. The developed model is applied to real education practice in an experiment then the results are analyzed to examine what kinds of effects there are in terms of various learning abilities of students and study achievements. By UPBI teaching and learning model, the nature of computer education was fully utilized so both online and offline study were allowed in parallel. In order to efficiently implement the UCC based learning system designed, skilled teachers’ ICT ability is required along with advanced school and home information facilities.

Automatic calibration of stratigraphic forward models for predicting reservoir presence in exploration

Understanding and predicting reservoir presence and characteristics at regional to basin scales is important for evaluating risk and uncertainty in hydrocarbon exploration. Simulating reservoir distribution within a basin by a stratigraphic forward model enables the integration of available prior information with fundamental geologic processes embedded in the numerical model. Stratigraphic forward model predictions can be significantly improved by calibrating the models to independent constraints, such as thicknesses from seismic or well data. A three-dimensional basin-scale stratigraphic forward-modeling tool is coupled with an inversion algorithm. The inversion algorithm is a modification of the neighborhood algorithm (a type of genetic algorithm), which is designed to sample complex multimodal objective functions and is parallelized on computer clusters to accelerate convergence. The process generates a set of representative geological models that are consistent with prior ranges for uncertain parameters, calibration constraints, and associated tolerance thresholds. The workflow is first demonstrated on two data sets: a synthetic example based on a clastic passive margin and a real hydrocarbon exploration example for slope and basin-floor stratigraphic traps in the Neocomian (Lower Cretaceous) of the West Siberian Basin. The analysis of calibrated models provides constraints on stratigraphic controls, and allows prediction of locations with higher potential to develop stratigraphic traps. These locations are related to complex interactions between paleobathymetry, subsidence, eustatic fluctuations, characteristics of sediment-input sources, and sediment-transport parameters. Results show the potential of stratigraphic forward modeling combined with inverse methods as an additional tool to support conventional play-based exploration and reservoir-presence prediction.