bluuebunny/crossref_metadata_2025 huggingface dataset:
ARTAM-WH: early predictive well health (WH) meta-monitoring tool
Authors: Goldschmidt Peter , Crawley Charles , Haq Bashirul , Palanisamy Santhosh
Published: August 2017

A well performing as expected is healthy. It is essential for efficient field operations to detect well health (WH) issues that may reduce the production efficiency and/or the overall recovery of an asset. The authors describe an early predictive WH meta-monitoring tool called ARTAM-WH, developed to assist maintaining stable operations (with high recovery). This is achieved by routinely checking the relevant individual WH parameters in context with the well’s operating environment.
As alert complexity increases so does the risk of false alerts. Moreover, existing systems raise alarms/alerts after significant deviation without completing extensive cross-checking. An early predictive and WH meta-monitoring tool is highly desirable. This study fills the gap.
ARTAM-WH is a new approach designed to provide early identification of existing or developing WH issues—precursors to WH problems if not addressed. ARTAM-WH uses in-situ monitoring systems—when available—or basic pressure, temperature and flow (gas, oil, water) data, coupled with static data, and conducts preliminary analysis and proper cross-checking and then notifies the engineers/operators. Differentiating this approach is that it is not looking at small data sets but at a large palate, including both static (well construct) and dynamic current performance versus performance expectations. ARTAM-WH provides supporting evidence of WH issues to the appropriate stakeholder. Notification includes the necessary and sufficient evidence derived from approximate reasoning algorithms combining multiple variables to identify possible issues and test the WH hypotheses.
ARTAM-WH frees up engineers/operators to focus on higher priority activities such as developing solutions. This allows for handling those problems through normal planning rather than emergency fixes.
Building long-term community partnerships in sensitive remote environments
Authors: van Beek Harris
Published: August 2017

Local communities can challenge the successful development of onshore oil and gas operations; for this reason, it is important to develop meaningful relationships with communities, where possible. As oil and gas companies establish more onshore operations it is necessary to find ways to build and sustain effective community relations.
Rio Tinto-Alcan (RTA) Weipa and Energy Resources Australia (ERA) are two significant resources operations in Australia that operate in sensitive remote environments. Positive, enduring and collaborative community relations are essential for the success of both operations. A partnership between each company and the schools within their respective local operating environment has created positive student outcomes and increased workforce stability, resulting in overall success for education and industry in the region.
This paper describes the long-term community partnership strategy that has been implemented to achieve mutually beneficial arrangements. It identifies how this experience can be used as a model to guide the oil and gas industry to establish sustained community relationships with its onshore operations, including CSG activities, in the future.
RTA and ERA have worked with Nous to create partnerships between the operations and their respective local schools. RTA and Western Cape College have partnered since 2005, and ERA has partnered with West Arnhem College since 2009. The starting point was identification of the school education and workforce needs of each partner, then aligning them through a partnership based around achieving mutual goals. Nous found RTA and ERA’s needs were to:
attract and retain staff;recruit local staff;improve Indigenous education and employment; and,support communities for a bright future and healthy young people.
The schools needed to ensure:
graduates have life choices and the capability to make decisions themselves;post-school pathways exist for students;students have diversified learning opportunities (both in the classroom and on the job); and,strong Indigenous communities are maintained, supported by leaders and young people.
Quality local school education is important to achieve these goals. The partnerships have established a broad program of activities to encourage young people to complete their schooling and forge pathways post-school. The development and maintenance of collaborative arrangements requires planning, action, leadership, coordination, and sustained commitment to achieve successful outcomes. This paper describes the approach, program initiatives and outcomes achieved, and how the approach can be adapted for onshore oil and gas operations.
Microstructural characterisation of organic-rich shale before and after pyrolysis
Authors: Uvarova Yulia , Yurikov Alexey , Pervukhina Marina , Lebedev Maxim , Shulakova Valeriya , Clennell Ben , Dewhurst David
Published: August 2017

Organic-rich shales, traditionally considered as source rocks, have recently become an ambitious goal for the oil and gas industry as important unconventional reservoirs. Understanding of the initiation and development of fractures in organic-rich shales is crucially important as fractures could drastically increase the permeability of these otherwise low-permeable rocks. Fracturing can be induced by rapid decomposition of organic matter caused by either natural heating, such as emplacement of magmatic bodies into sedimentary basins, or thermal methods used for enhanced oil recovery.
In this work the authors study fracture initiation and development caused by dry pyrolysis of Kimmeridge shale, which is characterised with a high total organic carbon content of more than 20%. X-ray diffraction (XRD) analysis exhibits high carbonate (both calcite and dolomite) and low clay (illite) content. Field emission gun scanning electron microscopy (FEG-SEM) shows that kerogen is presented either as a load-bearing matrix or as a filling of the primary porosity with pores being of micron size. Cylindrical samples of the Kimmeridge shale are heated up to temperatures in the range of 330–430°C. High-resolution X-ray microtomographic (micro-CT) images are obtained. The microtomographic images are processed using AVIZO (Visualization Sciences Group) to identify and statistically characterise large kerogen-filled pores and pre-existing and initiated cracks. The relationship between the total area of fractures and the temperature experienced by the sample has been obtained. Total organic carbon content is determined for samples subjected to heating experiments. This approach enables a quantitative analysis of fracture initiation and development in organic-rich shales during heating.
A laboratory procedure proposed for mechanical testing of shales
Authors: Minaeian Vida , Rasouli Vamegh , Dewhurst David
Published: August 2017

The authors have developed a laboratory procedure that uses a true triaxial stress cell (TTSC) to test cubes of rock instead of cylindrical-shaped samples. In this approach, three independent stresses are applied on the rock sample, which makes it possible to simulate field-conditions. Estimation of rock failure strength and deformation properties, while applying three stresses—rather than two as in case of conventional triaxial tests—is closer to the in-situ conditions. This is specifically important for shales due to their complicated transverse isotropic structure. The present study investigates the effect of minimum and intermediate principal stresses on the strength and elastic properties of gas shales. True triaxial experiments have been carried out on cubic shale samples from the Perth Basin under constant levels of minimum stress (~3 and 6 MPa) and varying magnitudes of intermediate principal stress (~3–40 MPa). Both minimum and intermediate stresses affect the rock strength through a non-linear trend. The behaviour of shales elastic modulus (E) with respect to varying σ2 tends to be similar to that of rock compressive strength. Poisson’s ratio in two directions along minimum and intermediate principal stresses (V13 and V12) does not show a simple dependency on the intermediate stress over the applied stress range. Finally, the observation of post-failure specimens revealed a significant influence of stress anisotropy on the failure mode, which evolves from dual to multiple shear faults.
Streamline, standardise, or specialise? Frameworks for regulation of unconventional resources in Australia
Authors: Brockett Richard
Published: August 2017

The growth in domestic and global demand for energy has encouraged the development of new and innovative sources of energy.
In Australia, the coal seam gas (CSG) industry has been in the vanguard of these advances with significant investment already in place to develop major CSG projects in Queensland. This rapid rise has highlighted the potential for other unconventional resources with proponents now exploring for new resources, such as shale gas, across Australia.
Governments have generally attempted to support the development of these new industries. Regulatory reform has addressed the bespoke regulatory issues presented by unconventional gas production particularly in respect of water, land access and co-existence with other industries.
Despite this the onshore gas industry continues to face political uncertainty, community division and divergent regulatory responses. Industry has consistently called for regulatory reforms to address duplication, remove unnecessary costs and improve approval processes to speed project delivery and enhance project returns while maintaining robust environmental protection obligations.
State and Federal governments have responded to these calls for action in varying ways. While there is much to approve of in each of these processes each presents specific issues and risks that must be considered before they are implemented or more broadly adopted. Therefore, the question arises: What is the best long-term regulatory approach for the sustainable development of Australia’s unconventional resources?
This paper reviews existing Australian regulatory approaches and analyses how regulators, industry and the community can work together to develop and implement a regulatory framework that achieves their respective objectives.
Australian states and Northern Territory acreage update
Authors: Haworth Jeffrey , Bruce Richard
Published: August 2017

It is encouraging to note that a number of international oil companies (IOCs) have taken an interest in Australian onshore exploration, including the following:
Bowen-Surat Basin—BG, ConocoPhillips, CNOOC, PetroChina, Sinopec, KOGAS, Mitsui, Petronas, Shell, and Total.Canning Basin—Mitsubishi, ConocoPhillips, Hess, PetroChina, and Apache.Cooper-Eromanga Basin—BG, and Chevron.Galilee Basin—CNOOC.Georgina Basin—Statoil, and Total.
There is now greater interest in Australian onshore exploration, including in a number of sedimentary basins that have previously largely been overlooked. New views on geology and the development of a commercial shale and tight gas sector in the US have prompted a reassessment of onshore petroleum potential, especially in SA, the NT and WA.
Access to onshore acreage in Australia for petroleum exploration is, in most jurisdictions, by means of a formal release process with a work program bidding system. Acreage that is being made available for exploration will generally be accompanied by information regarding its geological setting and petroleum prospectivity. Previous exploration activity may be summarised (including information in relation to the amount of pre-existing data available to applicants for acreage), and relevant maps and figures may be included. The following is a compilation of material supplied by the states and NT in relation to onshore acreage being made available for petroleum exploration.
US experiences in sustainable development of unconventional resources, appraisal phase approaches for addressing non-technical development risks
Authors: Sivapalan Mayuran
Published: August 2017

The global development of unconventional gas resources is progressing at a remarkable pace, owing to technology advancements, supportive regulatory environments, and expectations of favourable long-term market conditions. In Australia, the sheer scale of the resource potential, the increase in political and public will towards CO2 emissions reduction, and an immediate desire for greater local economic production suggests that exploration and production activity is likely to accelerate in the coming years. The unconventional gas sector, however, has been affected by negative publicity, with attention drawn to the potential environmental impacts and public burden associated with development practices—especially hydraulic fracturing. Stakeholder concerns regarding the significant water requirements, emissions footprint, and infrastructure impacts across the development lifecycle represent significant challenges. This extended abstract focuses on the use of structured decision-making approaches used in the appraisal phase of unconventional gas developments in the US to identify and manage the technical and especially non-technical risks that impact a development’s cost, schedule, and profitability across its lifecycle. An unconventional gas development from the US is presented, where a framework for integrating commercial, public, and environmental concerns from corporate and external stakeholders into field concept development and selection has been successfully applied. The development, which faces resource and regulatory challenges related to water management, air emissions, and local infrastructure impacts, employed fit-for-purpose decision-making tools that quantified non-technical development risks to inform the evaluation and selection of concepts that best met economic, corporate, and stakeholder expectations.
Well integrity management—a progressive approach to a major industry challenge
Authors: Smith Liane , O'Sullivan Enda
Published: August 2017

Integrity of the well and well system is of paramount importance, it is central to safe operation of any oil and gas facility and to the corporate and social reputation of the licenced operator to being a competent party to operate these facilities. Indeed, NOPSEMA’s misson statement is to independently and professionally regulate offshore safety, well integrity, and environmental management. This extended abstract highlights the importance of data as being core to knowledge and assurance of well integrity: what to monitor, how to manage that data, and ultimately how to interpret that data to determine the well condition and to ensure the safe operation of the wells. This extended abstract uses case studies that include more than 2,000 wells distributed across multiple operators, multiple fields, multiple countries, and multiple continents. Each has a unique story; however, a common element is the management of data spread across multiple third-party data systems, which have been successfully integrated in each case. More challenging is the range of data analysis and presentations customised for each client to achieve their goal of safe well operation. Examples of the data analysis and presentations include risk evaluation against complex criteria in individual well failure matrices, determination of tubing condition based on varying production conditions, managing well safe operating limits, and determining mean time to failure of equipment to establish risk-based inspection frequencies.
Automating the process of net environmental benefit analysis (NEBA) for emergency response and environmental plans
Authors: Williams Jack , Hooper Garnet , Hamilton Gregg
Published: August 2017

Each year in Australia, hundreds of referrals and environmental plans (EPs) are submitted to the regulatory agencies by oil and gas explorers. The plans assess multiple spill response options. One assessment tool is NEBA. This extended abstract presents a new approach for NEBAs and an automated NEBA process. This NEBA method has two scenarios: pre-spill and spill response. The pre-spill NEBA uses EP-defined sensitive receptors as appropriate examples in the region of interest, uses the modelling outputs to identify potential exposure zones, defines critical inputs (season, spill size), defines and ranks priority response according to the modelling output, and assesses spill response strategies. The output of the pre-spill NEBA is a table of response tactics to be assessed with respect to reducing risk to as low as reasonably practicable (ALARP). The spill response NEBA is similar to the pre-spill, but it uses real-time spill modelling data as an additional input to strengthen the data evaluation. Traditionally, both pre- and spill response NEBAs require considerable data input, extensive mathematical modelling, and human interpretation. Automating the NEBA process saves time, reduces errors, and minimises human biases in interpretation. ConocoPhillips has recently developed a tool to quickly conduct NEBAs. The NEBA tool also provides a means to document the progress of operational and scientific monitoring programs to measure the performance of the spill response. The automated process output can be time/date stamped to ensure critical steps are fully documented and auditable.
Mobilisation in a dynamic Australasian oil and gas market
Authors: Pink Vikki
Published: August 2017

How do major brownfield engineering, procurement, and construction (EPC) contractors manage their resources across a geographically dispersed market that is transitioning from the Greenfield mega-project era into operations? How do we manage seemingly unlimited opportunities with a finite in-country resource pool without compromising safety, quality and competitiveness? Contractors must demonstrate high levels of nimbleness and governance when it comes to accessing and deploying the right calibre, cost-effective resources. The mega-project era in Australia has seen unprecedented growth, but on a capital-project basis; brownfield contractors need to take the long view and structure their resourcing strategies accordingly. This means tapping into global networks of suitably experienced personnel, unblocking barriers to mobility, and developing sustainable development programs. Investment in and relentless focus on safety leadership through tailored development and competency programs is a must for any contractor that is serious about mobilising safely. When considering the cultural, behavioural, and competence contexts of diverse locations, leading contractors must come ready-armed with robust, proven tools managed by leadership personnel who are deeply intimate with these methods and the core values that underpin them. By taking direct ownership of resourcing through strategic, in-house capabilities with a global reach, a contractor can constantly monitor its talent pool and link this to its strategic opportunities. But even more critically, the contractor can provide assurance to clients and communities that the crews deployed to diverse worksites, such as Karratha, Bass Strait, and Papua New Guinea are completely fit for purpose and well suited to each environment.
All that is needed for evil to triumph is for good people to say nothing—human factors in effective safety-conversation interventions
Authors: Austin Jane
Published: August 2017

Intervening when we see others working unsafely is fundamental to achieving zero harm. Much research and anecdotal evidence indicates the positive impact that organisations experience when frequent and effective safety conversation interventions are the norm. Unfortunately, research across a number of industries and cultures indicates that all too frequently unsafe behaviours are not being addressed; further, when they are, the intervention is often ineffective in producing behavioural changes (Ragain et al, 2011). Many workers indicate that fear of an angry, defensive response or that their attempts will not make a difference stop them from intervening when observing unsafe behaviours in the workplace (Ragain et al, 2011). This extended abstract explores the human factors that play a role in effective safety conversation interventions. Specifically, it discusses the impact of team psychological safety, the role of in-group versus out-group assessment, attribution error and self-efficacy on the likelihood that the worker will intervene or not, and the effectiveness of any safety conversation intervention. Also explored are the human factors issues behind the use of skills or strategy that are positively associated with effective safety conversation interventions such as pre-framing, questioning techniques, focus on consequences, rapport building and active listening.
Petroleum Prospectivity of the Tasman Frontier
Authors: Bache Francois , Stagpoole Vaughan , Sutherland Rupert , Collot Julien , Rouillard Pierrick , Hackney Ron , Rollet Nadege , Hashimoto Takehiko
Published: August 2017

The Fairway Basin lies between Australia and New Caledonia in the northern Tasman Frontier area with water depths ranging from less than 1,000–2,400 m. This basin was formed in the mid-to-late Cretaceous during the eastern Gondwana breakup and since then has received detrital and pelagic sediments. It is known for its 70,000 km2 bottom simulating reflector, interpreted as one of the world’s largest gas hydrate layers or as a regional diagenetic front. The seismic reflection data shows sedimentary thicknesses (up to 4 km) and geometries capable of trapping hydrocarbons. The authors interpreted the seismic stratigraphy and available well data in terms of paleogeography and tectonic evolution. This work allowed the discovery of a deeply buried delta, probably of the same type as the deep-water Taranaki Delta. This stratigraphic framework is used to constrain multi-1D generation modelling and to test three main hypotheses of source rocks. The most likely scenario, similar to the one accepted for the Taranaki petroleum province, are a type-III and type-II source rocks intercalated in a Cretaceous prograding series. Another possible scenario is a source rock equivalent to the east Australian Walloon Formation and the occurrence of the marine source rock in the pre-rift sequence. Although, the large modelled volumes at this stage are speculative due to limited data on source rock composition, richness and distribution, as well as on the presence and quality of reservoir and seal, this study confirms the prospectivity of the Fairway Basin and the need for more data to further assess this basin.
New, lower cost, gas development concepts using advanced subsea gas processing: the end of the surface gas giants?
Authors: Moore Richard
Published: August 2017

Offshore gas developments in the 1980s and 1990s typically involved cooling, water removal, and dehydration on a fixed platform. As the industry moved into deeper water, the flow assurance and processing challenges have greatly broadened; however, many highly preferred processing options, which have been available on topsides facilities, remain unavailable subsea. The result has been an over-reliance on glycol injection, with very significant, but often unrecognised, challenges and large cost implications. Despite being immersed in cool seawater, accurate control of hydrocarbon temperature subsea is not presently available. The dangers from excessive cooling, leading to wax and hydrate formation, mean that cooling without temperature control (passive cooling) is not acceptable. Accurate, temperature controlled, subsea cooling technology combined with separation opens up an entirely new category of flow assurance solutions and advanced subsea processing opportunities, with enormous potential benefits. FLNG pre-processing, deepwater hub developments, and even dry single phase export are all possible. Combined with subsea compression, the requirement to bring gas to surface is eliminated completely. The avoidance of gas to surface and the huge facility sizes and cost this entails opens the way for dramatically lower cost gas developments, necessary for Australia to remain competitive in today’s world.
Structuring your farmin in an unconventional world
Authors: Fulcher Jonathan , Klapper Martin , Roe Damian
Published: August 2017

This extended abstract and its presentation explore the legal aspects of good planning and implementation of a successful farmin—from the perspectives of the farmor and the farmee. Among other things, this extended abstract addresses the common and some unusual farmin obligations and structures available to achieve the purpose of the farmin. A common issue is when the tenement interest is transferred—the presentation discusses at the implications. The position under relevant tax and state duty rulings are also examined. The presentation further addresses the farmin program and structuring impacts of force majeure, permit commitments, and overlap in a multistage farmin; and, the development of a joint operating agreement (JOA) that could start during or after farmin obligations are completed. The implications of different majority voting percentages in an operating committee under a JOA, which starts about the same time as a farmin in which participating interest shares increase in stages (also be briefly examined).
Petroleum implications of stacked deltas in the Fairway Basin, offshore New Caledonia, Northern Tasman Frontier
Authors: Rouillard Pierrick , Collot Julien , Bache Francois , Sutherland Rupert , Kroeger Karsten , Funnell Rob
Published: August 2017

The Fairway Basin lies between Australia and New Caledonia in the northern Tasman Frontier area with water depths ranging from less than 1,000–2,400 m. This basin formed in mid-to-Late Cretaceous during eastern Gondwana breakup and received detrital and pelagic sediments since that time. It is known for a 70,000 km2 bottom simulating reflector interpreted as either one of the world’s largest gas hydrate layers or as a regional diagenetic front. Seismic reflection data shows sedimentary thicknesses (up to 4 km) and geometries capable of trapping hydrocarbons. We interpret seismic stratigraphy and available well data in terms of paleogeography and tectonic evolution. This work allowed the discovery of a deeply buried delta probably of the same type as the deepwater Taranaki Delta. This stratigraphic framework is used to constrain multi-1D generation modelling and to test three main hypotheses of source rocks. The most likely scenario, similar to the one accepted for the Taranaki petroleum province, are a type-III and type-II source rocks intercalated in Cretaceous prograding series. Another possible scenario is a source rock equivalent to the East Australian Walloon Formation and occurrence of marine source rock in the pre-rift sequence. Although large modelled volumes at this stage are speculative due to limited data on source rock composition, richness and distribution, as well as on the presence and quality of reservoir and seal, this study confirms the prospectivity of the Fairway Basin and the need for more data to further assess this basin.
Influence of faulting on reservoir overpressure distribution in the Northern Carnarvon Basin
Authors: Hoskin Edward , O'Connor Stephen , Robertson Stephen , Streit Jurgen , Ward Chris , Lee Jack , Flett David
Published: August 2017

The Northern Carnarvon Basin has a complicated geological history, with numerous sub-basins containing varying formation thicknesses, lithology types, and structural histories. These settings make pre-drill pore pressure prediction problematic; the high number of kicks taken in wells shows this.
Kicks suggest unexpected pore pressure was encountered and mudweights used were below formation pressure. The horst block penetrated by the Parker–1 well is focused on in this peer-reviewed paper. This horst is one of many lying along Rankin Trend’s strike. In this well, kicks up to 17.2 ppg (pounds per gallon) were taken in the Mungaroo reservoir. The authors investigate whether the kicks represent shale pressure—or rather, represent pressure transferred into foot-wall sandstones—by using well data from Forrest 1/1A/1AST1 and Withnell–1, and wells located in the Dampier Sub-basin and the hanging-wall to the horst. This anomalous pressure could result from either cross-fault flow from juxtaposed overpressured Dingo Claystone or transfer up faults from a deeper source.
Using a well data derived Vp versus VES trend, the authors establish that the kicks taken in Parker–1 are more likely to result from pressure transfer using faults as conduits. These data lie off a loading trend and appear unloaded but likely represent elevated sand pressures and not in situ shale pressure. Pressure charging up faults in the Northern Carnarvon Basin has been recognised in Venture 1/1ST1, however, this paper presents a focused case study.
Pressure transfer is noted in other basins, notably Brunei. From unpublished data, the authors believe that buried horst blocks, up-fault charging and adjacent overpressured shale may explain high reservoir pressures in other basins, including Nam Con Son in Vietnam.
An integrated approach to defining well placement strategies for heterogeneous CSG reservoirs
Authors: Brown Luke , Hultzsch Paul , Roy Ananda Shankar , Neber Alexander , Farrow Michaela
Published: August 2017

Operators developing the vast CSG resources held in the Surat and Bowen basins of Queensland, Australia, face significant challenges. Given the heterogeneous nature of CSG reservoirs, and often sparse data from wells and 2D seismic, there are significant uncertainties regarding reservoir quality and productivity. The prolific number of wells required to extract the economic reserves (more than 30,000) requires workflows that can efficiently integrate information for rapid development planning.
Traditionally, most of the efforts dedicated to assessing uncertainties in CSG reservoirs focus on the estimation of the gas-in-place (GIP), and how it varies laterally. Variations in productivity (mainly dependent on permeability) are usually more abrupt, have a larger impact on project economics, and are far less understood than the GIP. Authors such as Chopra and Marfurt (2012) have recently developed analytical methods using 3D seismic attributes to identify fractured areas with higher permeability. As well as permeability, other factors influencing productivity, such as GIP, thickness, depth and saturation, must be combined to define a complete well placement strategy.
In this study, the authors propose a holistic approach for the assessment and integration of the uncertainties in CSG reservoirs, using the Baralaba Coal Measures in the Bowen Basin as a case study to demonstrate the workflow. Various seismic attributes are used to identify fracture drivers associated with faulting and folding around the Burunga Anticline structure, and map areas predicted to have higher permeability, calibrated against well production. Chance-of-success mapping is used to integrate the permeability heterogeneities with traditional well-derived maps of coal properties, such as gas content, to isolate sweet spots in the CSG reservoir. The integrated model is transformed into geological pseudo-cost and combined with surface development costs and restraints to automatically generate potential well placement scenarios.
2015 Offshore Petroleum Exploration Acreage Release
Authors: King Demus
Published: August 2017

The oil and gas sector is a key contributor to the Australian economy, contributing $30.8 billion in commodity export earnings in 2013–14 (Department of Industry and Science, 2015). Underpinning future growth in the value of oil and gas to the Australian economy is the almost $200 billion of investment in seven LNG projects under construction. Australia relies on foreign capital to continue to explore for, and develop, its natural resources.
New challenges and opportunities are arising for the sector. Increased international competition, advancing technology, and increasing risks and volatile costs associated with the development of fields are features of the current offshore operating environment. Australia’s legislative and policy settings must be sufficiently robust and flexible to support the continued development of Australia’s offshore resources into the future.
To this end, the Australian Government is undertaking a high-level strategic review of the resource management framework for offshore petroleum resources in Commonwealth waters. The review will test the robustness of the policy, legal and regulatory regime to ensure the framework remains flexible enough to keep pace with the evolving environment and continues to attract investment.
The annual Offshore Petroleum Exploration Acreage Release facilitates new investment in offshore petroleum exploration. The 2015 Acreage Release is accompanied by an updated exploration guideline. The guideline increases flexibility in permit management and clarifies competitive work program bidding expectations and good standing as well as providing more flexibility in the way good standing agreements may be discharged. This will enable industry to undertake exploration with increased autonomy and reduce the administrative burden. It accommodates changing technological capacity and encourages increased exploration in Australia’s offshore waters.
Towards updated stratigraphic frameworks for Australia
Authors: Smith Tegan , Ogg James , Kelman Andrew , Abbott Steve , Bernecker Thomas
Published: August 2017

A standardised and precise timescale is invaluable to geological research and crucial to meaningful correlation at local, regional and global scales for both researchers and industry. Modern techniques and instruments are delivering increasingly accurate ages, and biozonation schemes are continually refined and standardised on a global basis. Updates to the international geologic time scale occur regularly, and constant updates to stratigraphic schemes are required to ensure that major regional geological events can be correlated across the Australian margin.
Several different sequence stratigraphic schemes have been developed for the basins of the North West Shelf. These range from basin-specific to margin-wide schemes. While these schemes have much in common, there are some significant differences. Understanding the nature and reasons for both the differences and commonalities is an essential step for improving understanding of the region’s evolution. The continuing improvements being made to biostratigraphic zonation schemes for the Triassic to Cenozoic will assist in better defining sequences and correlations, and allow geologists to better understand whether apparent differences in sequence definition across the margin are real, and therefore if they reflect different basin histories or are simply an artefact of biostratigraphic imprecision.
Geoscience Australia endeavours to—in collaboration with industry—produce unified stratigraphic schemes for the various hydrocarbon provinces. This work will fundamentally support present and future acreage releases.
Interlaminar modelling to predict composite coiled tube failure
Authors: Mishani Siamak , Evans Brian , Rasouli Vamegh , Roufail Reem , Soe Soren , Jaensch Peter
Published: August 2017

In a field operation that uses coiled tubing in its applications, fibre-reinforced polymer matrix composite tubing is seldom used. Fibre-composite coiled tubes offer advantages, compared to steel material, through a reduction in weight and improvement in fatigue life.
The stiffness of composite material degrades progressively when increasing the number of cyclic loading. The fatigue damage and failure criteria of fibre-reinforced composite coiled tubes are more complex than that of steel; hence, failure predictions are somewhat unreliable.
Among the defects in composite materials, interlaminar delamination is the foremost problem in fibre-reinforced composite material, and it leads to a reduction in strength and stiffness especially in cyclic-load conditions. Delamination causes a redistribution of the load path along the composite structure, which is unpredictable; therefore, delamination in a composite coiled tube in an oil and gas field eventually leads to final failure, which could be catastrophic.
A-ply-by-ply mathematical modelling and numerical simulation method was developed to predict interlaminar delamination of filament-wound composite coiled tubes under a combination of different loading scenarios with consideration to low-cycle fatigue.
The objective of this paper is to explain interlaminar delamination as an initial crack and source of stress concentration in composite coiled tubes in the framework of meso-cracking progression of matrix damage modelling of composite laminates.
The paper focuses on delamination failure because the largest span of the composite lifecycle is at the crack propagation phase, which manifests itself in the form of delamination. The analysis shows that the crack front tip is not uniform, and also shows that carbon fibre possesses higher stiffness values compared to glass fibre. The paper confirms that 2D modelling cannot express the real release strain energy rate at the crack front tip. Mode-I testing, however, showed that the double cantilever beam (DCB) only represents the normal stress from the release strain energy rate. The results also indicated that there were other sources contributing to the strain energy release rate, such as inter-layer frictions and normal stress in the end notched flexure (ENF) testing mode.
Rift processes in the Westralian Superbasin, North West Shelf, Australia: insights from 2D deep reflection seismic interpretation and potential fields modelling
Authors: Belgarde Catherine , Manatschal Gianreto , Kusznir Nick , Scarselli Sonia , Ruder Michal
Published: August 2017

Acquisition of long-offset (8–10 km), long-record length (12–18 sec), 2D reflection seismic and ship-borne potential fields data (WestraliaSpan by Ion/GXT and New Dawn by PGS) on the North West Shelf of Australia provide the opportunity to study rift processes in the context of modern models for rifted margins (Manatschal, 2004).
Basement and Moho surfaces were interpreted on seismic reflection data. Refraction models from Geoscience Australia constrain Moho depth and initial densities for gravity modelling through standard velocity-density transformation. 2D joint inversion of seismic reflection and gravity data for Moho depth and basement density constrain depth to basement on seismic. 2D gravity and magnetic intensity forward modelling of key seismic lines constrain basement thickness, type and density. Late Permian and Jurassic-Early Cretaceous rift zones were mapped on seismic reflection data and constrained further by inversion and forward modelling of potential fields data.
The Westralian Superbasin formed as a marginal basin in Eastern Gondwana during the Late Permian rifting of the Sibumasu terrane. Crustal necking was localised along mechanically-weak Proterozoic suture belts or Early Paleozoic sedimentary basins (such as Paterson and Canning). Mechanically-strong cratons (such as Pilbara and Kimberley) remained intact, resulting in necking and hyper-extension at their edges. Late Permian hyper-extended areas (such as Exmouth Plateau) behaved as mechanically-strong blocks during the Jurassic to Early Cretaceous continental break-up. Late Permian necking zones were reactivated as failed-rift basins and localised the deposition of the Jurassic oil-prone source rocks that have generated much of the oil discovered on the North West Shelf.
Why the wait? Shale gas exploration review and look ahead
Authors: Close David
Published: August 2017

Despite unconventional targets being recognised across many Australian sedimentary basins and the Energy Information Administration (EIA), estimating a technically recoverable shale gas resource of >400 tcf in Australia, there have been no definitive tests that prove that any of these potential plays will flow gas at commercial rates. There has, however, been a number of technical successes reported from both shale gas and basin centred gas plays.
This extended abstract reviews select plays from both frontier and mature basins across Australia, including basins where Origin is actively exploring or appraising unconventional gas plays—the Perth, Cooper and Beetaloo basins. The technical challenges vary from play to play, but many of the above ground challenges are not play specific.
To advance the industry, Origin and other companies will have to demonstrate a resource sufficiency that is economic in a high cost environment like Australia, while maintaining a positive relationship with communities.
In its expansion into the NT, through its interest in the Beetaloo Basin, Origin has the benefit of 20 years' experience dealing with complex stakeholders and environmental challenges through its CSG development projects in Queensland. This experience is invaluable in advising best practices for engaging with local communities, landholders, traditional owners, and regulatory and government bodies.
For the technically-minded asset development teams charged with exploring unconventional plays in frontier basins, where stakeholders are unfamiliar with oil and gas development projects, new skills are required that need deep organisational support.
Conventional and unconventional hydrocarbon resource economics
Authors: George Bob , Rousset Florent , Cui Cecilia Jing , Yan Tianjiao
Published: August 2017

The abundance of unconventional hydrocarbon resources in North America is not unique, though it is the only region that has seen significant progress in extracting and monetising these resources.
Many countries have successful conventional exploration and production activities, and have developed suitable fiscal terms and governance models, but these models are challenged with the relevancy of these terms when applied to unconventional resource exploration, evaluation and development.
This extended abstract reviews factors that are largely in the control of a host government (for example, the fiscal, licensing and regulatory system), and where challenges lie in cost disadvantages (the provision of services and infrastructure, for which different considerations and approaches need to be applied).
It also compares the fundamental economic characteristics between similar-sized investments in an onshore unconventional play and in a conventional oil field in deepwater.
Previously, the authors compared these investments in a US environment and the same characteristics will be used for examining typical terms in other environments around the world.
By isolating impacts from leasing and fiscal terms, the economics will also be analysed before the overlay of fiscal terms, and then with a royalty/tax and a generic production sharing contract type of fiscal regime.
The findings will help in understanding what can facilitate and accelerate the development of unconventional resources, and which enabling environments might be required to attract resources such as capital, technology and expertise.
Attributes and behaviours of crude oils that naturally inhibit hydrate plug formation
Authors: Aman Zachary , Syddall William G.T. , Pickering Paul , Johns Michael , May Eric F.
Published: August 2017

The severe operating pressures and distances of deepwater tiebacks increase the risk of hydrate blockage during transient operations such as shut-in and restart. In many cases, complete hydrate avoidance through chemical management may be cost prohibitive, particularly late in a field’s life.
For a unique subclass of crude oils, however that have not been observed to form a hydrate blockage during restart, active hydrate prevention may be unnecessary.
In the past 20 years, limited information has been reported about the chemical or physical mechanisms that enable this particular non-plugging behaviour. This extended abstract demonstrates a systematic method of characterising this oil, including:

physical property analysis that includes and builds upon ASTM standards;
water-in-oil emulsion behaviour; and,
the effect of oil on hydrate blockage formation mechanics.

This last set of experiments uses a sapphire autoclave to allow direct observation of hydrate aggregation and deposition, combined with resistance-to-flow measurements. The effect of shut-ins and restarts on the oil’s plugging tendency is also studied in these experiments. The method was tested with several Australian crude oils, some of which exhibited non-plugging behaviour.

In general, these particular crude oils do not form stable water-in-oil emulsions but do form stable non-agglomerating hydrate-in-oil dispersions. The oils suppress hydrate formation rates and their resistance-to-flow does not increase significantly when the amount of hydrate present would normally form a plug.
Exploring unconventional plays in the Georgina Basin, central Australia: will the real Arthur Creek Formation hot shale please stand up!
Authors: Willink Robbert , Allison Mitch
Published: August 2017

The search for hydrocarbons in the southern Georgina Basin in central Australia is now focused on assessing the unconventional potential of the Middle Cambrian lower Arthur Creek Formation.
Recent regional well correlation studies, supported by a review of nominated type sections and of regional seismic data, and integrating core-based sedimentological, palaeontological, chemostratigraphic, and geochemical information, suggest that the organic rich hot shale at the base of this formation, encountered in wells drilled in the Dulcie Syncline, is not a correlative of the organic rich hot shale encountered in wells drilled in the Toko Syncline.
Although similar in lithofacies and mineralogy, the former is significantly older and is more restricted in geographic distribution to an area west of a prominent northwest to southeast trending shear zone in the basement.
This interpretation is contrary to correlations presented in recent publications on the geology and resource potential of the southern Georgina Basin by government agencies, various petroleum consultancy firms that have provided estimates of the volumetric potential of the unconventional hydrocarbon resources in the lower Arthur Creek Formation, and several petroleum companies actively exploring in the basin.
Any historical inference that simply assumed the lower Arthur Creek Formation hot shale in the Toko domain should be an attractive unconventional target because of the lithological properties of the lower Arthur Creek Formation hot shale observed in the Dulcie domain is not supported by these revised correlations. Pursuit of the basal lower Arthur Creek Formation unconventional play in the Dulcie Syncline and in the Toko Syncline should be done on their respective merits.