bluuebunny/crossref_metadata_2025 huggingface dataset:
Sweet-spot mapping of the Goldwyer Formation through formation evaluation and property modelling in the Canning Basin, Barbwire Terrace case study
Authors: Alshakhs Munther , Rezaee Reza
Published: June 2017

The Goldwyer Formation of the Canning Basin has been regarded as a highly prospective shale petroleum play. This study assesses the potential prospectivity of this source rock as an unconventional hydrocarbon resource via property modelling. Considering the sparsity of wells penetrating the Middle Ordovician Goldwyer across the vast under-explored area of the Canning Basin, a basin-wide study of the source rock is not justified. Due to a higher well density, assessment of the Goldwyer Formation within the Barbwire Terrace, a sub-division of the Canning Basin, is carried out instead.
This assessment includes the estimation of key shale play properties, such as, total organic carbon, total porosity, water saturation, and brittleness. Each property was estimated from available well wireline log data by testing multiple estimation methods. Total organic carbon values were derived from multiple regressions of different well data. A simplified Archie’s equation was used to estimate water saturation. Density porosity method was used for total porosity estimations. Sonic data along with density were utilised to estimate the brittleness index.
Each property was then modelled across the Barbwire Terrace, which provided geostatistical estimates on the propagation of each parameter. In order to generate sweet spot maps, averaged maps of the properties were combined in a weighted manner.
In the model, the Goldwyer Formation was divided into three layers based on dominant lithology. The uppermost shale dominated layer was predicted by the model to be the most prospective stratigraphic zone. The sweet spot maps highlight the southern flanks of the northern and western part of the Barbwire Terrace as the highest prospective geographic locations. This approach attempts to simplify the complexity of unconventional resource assessment, and has provided a single product evaluating the prospectivity of the Goldwyer as a hydrocarbon resource.
FLNG innovation: discover development hotspots with patent landscaping
Authors: Baddeley Richard H.
Published: June 2017

Innovation and corresponding patent activity in the liquefied natural gas (LNG) production field grew strongly over the period 1997–2016, reaching a peak in 2013–14. A patent landscaping analysis enabled a preliminary investigation of innovation foci, by technical subject matter, and those companies driving such innovation. Floating LNG (FLNG) innovation so far forms a small proportion of this activity, yet shipbuilding companies like Daewoo Shipbuilding and Marine Engineering, Samsung Heavy Industries and Hyundai Heavy Industries are relatively dominant innovators, as measured by patent intensity, likely collaborating – for FLNG projects – with operating companies like Shell and ExxonMobil which are also significant, although statistically less dominant, innovators in the LNG production field. Patent landscaping analysis also showed that key foci for innovation appear in the fields of LNG storage tanks, carbon dioxide and boil-off gas management. Further investigations would provide more specific information about innovation occurring in these fields of LNG production.
A practical workflow for performance prediction of low permeability reservoirs
Authors: McMullen Arthur L. , Golko Steven J.
Published: June 2017

The Society of Petroleum Evaluation Engineers (SPEE) recently released ‘Monograph 4 – estimating ultimate recovery of developed wells in low-permeability reservoirs’ (hereafter called ‘Monograph 4’; SPEE 2016). This paper outlines a practical engineering workflow enabling companies to evaluate unconventional plays developed with horizontal multi-stage fractured wells consistent with the principles summarised in Monograph 4. This workflow has many applications including assessing potential acquisitions, defining new plays, evaluating competitor results, corporate budget processes, long-term business planning, portfolio management and reserves certification.
The workflow, developed and refined over several years, has proven effective in large-scale applications. It enables engineers to readily identify and assess flow regimes, estimate the time to boundary dominated flow and estimate the flow patterns of boundary dominated flow for large groups of wells. The workflow also allows the engineer to deal with changing well designs and completion techniques. Throughout the workflow, the geological, engineering and statistical methods described in Monograph 4 are used. This provides the foundation to define and create representative type curves, yielding statistically reliable estimates of expected ultimate recovery (EUR) and production forecasts for asset evaluation with an accompanying characterisation of the confidence of these estimates.
A case study demonstrating application of this workflow and a summary of results are presented. Potential sources of error in the technical analysis and application of type curves are identified; the technical and commercial impacts of these errors are highlighted.
By allowing the evaluator to focus time and attention on the details of the technical analyses, companies can achieve a quicker, more in-depth analysis of the development of these large-scale unconventional resource projects.
Galvanising the opposition: social media campaigns and the new risks for the oil and gas industry
Authors: Glindemann Robyn
Published: June 2017

Globally, the oil and gas industry has been at the forefront of social licence to operate issues for over 20 years: from Brent Spar in the North Sea in the mid-1990s to the Greenpeace-led Lego campaign in 2014.
However, the increasing demand from stakeholders for transparency from both companies and regulators, combined with the use of social media platforms to bring disparate groups of people together and globally disseminate information, has created new issues and risks for the industry to manage, often within compressed timeframes.
To date, the focus of environmental groups has been on exploration activity in the oil and gas sector. The formation of the Great Australian Bight Alliance to oppose the development of resources in the Great Australian Bight, the Wilderness Society’s freedom of information (FOI) request for BP’s oil spill modelling data (which was the subject of an August 2016 decision from the Commonwealth Administrative Appeals Tribunal) and the rise of the Lock the Gate Alliance in the context of the onshore gas sector are three examples of mixing traditional protest tactics with social media strategies.
Using these and other examples, this paper will discuss the new issues and risks that oil and gas companies and regulators have to address as a consequence of social media being added to the stakeholder arsenal, and consider what new issues may arise in the social licence to operate space as the industry begins to address decommissioning and rehabilitation issues.
Marine seismic acquisition: efficiency and environment, new technologies applied in Australia
Authors: Bayly Martin , Tham Michelle , Watterson Peter , Li Binghui , Moran Kevin
Published: June 2017

The design of successful marine seismic surveys is driven by many factors, two prime issues being efficiency and environmental impact. Efficiency is primarily driven by reduction of non-productive time and creating the largest sub-surface illumination area possible in the shortest time. In addition, public opinion and governmental regulations are requiring the industry to minimise their environmental impact. One aspect is reducing the overall sound exposure level (SEL) of the source into the marine environment. Using recent Australian examples, we will discuss and demonstrate the use of two new technology groups that address these concerns.
The first is the use of a new type of seismic air-gun with optimal output over the range of frequencies commonly used in seismic exploration, while limiting potential environmental effects from unnecessary high-frequency emissions. The second is continuous data acquisition along the entire boat traverse, including the turns, thereby reducing non-productive vessel time. Both are described with examples from a recent survey acquired offshore north-west Australia.
Lean offshore platform design
Authors: Sage Drew , Bieganski Michael , Grant Andrew
Published: June 2017

Current industry practices of prescriptive design and duplication of previous work on offshore oil and gas facilities have often caused relatively simple design requirements to be executed as large, maintenance-heavy, expensive platforms. The question of whether equipment is technically justified is rarely asked, and the potential benefits of minimised systems are rarely realised.
By adopting lean design thinking, where all equipment must be technically justified as essential to operation before being included on the platform, the benefits are twofold. First, personal safety is improved because less equipment is required to be maintained offshore, meaning fewer offshore man-hours. Second, significant cost savings can be achieved because less offshore equipment means smaller platforms.
This paper outlines the design, operating, manning and maintenance philosophies that form the basis for lean design thinking, and the effect this thinking has on both offshore man-hours and facility costs. Two case studies have been undertaken to evaluate the quantifiable differences between conventional platform design and lean platform design. Aker Solutions’ Lean Semi has been compared with a conventional semisubmersible platform to show that substructure weight savings of up to 30% are achievable; in addition, Aker Solutions’ Hybrid Compression Facility has been compared with a conventional compression platform to show that topsides weight savings of more than 50% are achievable.
Uncharted waters: LNG as a marine fuel in Australasia
Authors: Duncanson Rob , Purio Walter P.
Published: June 2017

This paper explores the emerging market for liquefied natural gas (LNG) as a marine fuel, with a particular focus on the market in Australasia. While LNG as a marine fuel is a growing market in the northern hemisphere, slower rates of adoption of LNG fuel technologies in maritime industry are evident in the southern hemisphere. This paper aims to ground the Australasian LNG marine fuel market in a global context and to explore opportunities for Australia to lead the region in developing and adopting LNG as a marine fuel. This paper looks at the key drivers behind championing LNG as a marine fuel, focusing on four main areas of impact; economy, environment, public health and innovation. This paper uses Australia as a case study for the adoption of LNG as a marine fuel in the southern hemisphere. It considers the opportunities presented by LNG as a marine fuel to assist Australia in: achieving energy independence; reducing the impact of air pollution from ships on the environment and public health; and positioning Australia as an innovative leader in LNG as a marine fuel.
Advanced directional CwD system pushes integration envelope to elevate efficiencies and reduce costs
Authors: van Og Geertjan , Burgerhout Jeroen
Published: June 2017

The evolution of casing while drilling (CwD) illustrates the economic, efficiency and health, safety and environment benefits achievable with the seamless integration of downhole tools and surface drilling equipment. However, several technology gaps have restricted CwD from reaching its full potential to optimise the well construction process.
This paper describes the integrated development and application of a retrievable Enhanced Casing Installation (ECI) system, engineered to take directional (Level 3) casing drilling technology to another level and further expand the functionality of both specialised and standard land drilling rigs. The system, which enables directional drilling with composite casing and standard mud motors, differs from typical Level 3 CwD methodologies in that the composite option allows bottom hole assembly (BHA) placement inside the shoetrack, thus helping reduce vibrations and wear on the reamer and other downhole tools. Along with increased well stability and allowing simultaneous logging/measuring while drilling, the ECI device is configured with a comparably lightweight BHA, requiring fewer components, such as jars and roller reamers, making it easily retrievable with cable. As discussed, the cost-effective integration of downhole and surface equipment is clearly reflected in the capacity to rerun the retrieved bit and reamer – a marked difference between the sacrificial bits required for the commonly used Level 2 (vertical) CwD technique.
Moreover, the authors will present results of a specialised test stand evaluation and subsequent field trial, where the system was integrated on a fit-for-purpose rig and used for casing drilling at a 45° angle with the BHA pulled intact from 1800 m MD.
The Internet of Things (IoT) is transforming the oil and gas industry – reducing cost, improving operational efficiency, increasing safety and helping tap into new markets
Authors: Hogarth-Scott Piers
Published: June 2017

The Internet of Things (IoT) and its forecast 50 billion+ devices will transform industries with an estimated $11+ trillion annual impact to the global economy by 2025. In that same period, Australia has the opportunity to derive up to $116 billion in annual economic value from IoT.
The IoT is taking the internet into everything that impacts our lives – from engineering to health, infrastructure, agriculture, mining and more. It is the future of digital connectivity, data accumulation and system efficiencies, but implementation requires sound strategy with a balance between innovation, opportunity and risk.
KPMG views IoT as an opportunity for Australian technology companies, industries and entrepreneurs to be leaders in the development and execution of innovative IoT applications. The potential economic, social and environmental benefits from effective IoT solutions are vast. However, IoT developments must focus on security, privacy and trust, to ensure the safety of the IoT ecosystem and its users.
The oil and gas industry have in many ways been leaders in the industrial IoT, recognising that innovation in IoT can reduce cost, improve operational efficiency, increase safety and help tap into new markets. However, to unlock the full economic opportunity presented by IoT, interoperability of technologies is essential. This paper explores IoT interoperability with a particular focus on Hypercat BSI PAS212:2016.
Recirculation to improve progressive cavity pumps (PCPs) run life
Authors: Martin Jonathan
Published: June 2017

Progressive cavity pumps (PCPs) are widely used as a method of artificial lift, commonly found in coal seam gas (CSG) wells in Queensland. One of the major challenges with PCPs is the pump torqueing up due to solids and not being able to restart, which results in lost production and the need for intervention with a flush-by unit or service rig. Up to 30% of PCPs in the Surat Basin can be down at any given time on account of this issue.
We have engineered a solution whereby fluid is produced using the existing PCP, a desander is used to remove solids and the clean fluid is reinjected down the annulus, via hollow rods or by a capillary string. This complete system has many benefits: it removes sands and solids from the wells produced water stream; and it reinjects clean water down the well bore, which serves the dual purpose of diluting the concentration of downhole solids and, via the introduction of additional clean fluid, allows the PCPs to be sped up, thus increasing the velocity to aid in lifting the solids out of the well.
This can all be done at a fraction of the cost of intervention with a flush-by unit or service rig. Lessons learned from field trials to date include: (1) how to account for loss of reinjected fluid in early field trials, which was solved by the introduction of hollow rods; (2) increasing PCP speed for 1 h per day to clear the solids, as a preventative flush; (3) verification of solids issues in CSG wells in the Surat Basin; and (4) quantification of produced solids.
Interpretative filtering
Authors: Ajjabou Leïla , Bourdais Maëlle , Gritsajuk Natalia , Lacaze Sébastien , Adam Jean-Philippe
Published: June 2017

Industry already acknowledges the power of dip-steered median filters to clean-up seismic data volume in which coherent events are enhanced and random noise is reduced. By combining two powerful technologies, this paper presents a dip-steered geostatistical filtering solution, called interpretative filtering (IF), which gives remarkable results for removing random and organised noise from seismic volumes. It defines a new generation of spatial filters useful for processing and interpretation. The IF solution is based on a 3D non-stationary factorial kriging technique (M-GS technology) driven by a high-resolution interpretation of the seismic volume coming from a Relative Geological Time model. This new technique enables some non-stationary noise to be dealt with. For example acquisition footprints are well known to be non-stationary noises, with varying orientation, width and intensity as a function of the position in the volume. IF opens the way to refine filtering operations of seismic volumes even in complex structural environments. For this paper, the solution is applied to an open-file 3D marine seismic dataset (HCA2000A 3D) covering the Exmouth sub-basin, North West Shelf, Australia. This survey presents a dense fault system, mostly intersecting the Jurassic and the Cretaceous. Results show a great improvement on reducing the acquisition footprint and random noise without compromising the definition of the subtle geological features.
What happens when quantum computing re-defines the assessment of investment risk?
Authors: Laybourn Mark , Pascoe John
Published: June 2017

The dawn of quantum computing is upon us and as the world’s smartest minds determine how the technology will change our daily lives, we consider how it could benefit investors in oil and gas projects to make better decisions.
The oil and gas industry relies on investment for its survival and investors expect a return commensurate with the risks of a project. The classical approach to investment evaluation relies on mathematics in which estimated project cash flows are assessed against a cost of capital and an upfront investment. The issue with this approach is the key assumptions which underpin the project cash flow calculations such as reserves, production and market prices are themselves estimates which each introduce a degree of risk.
If we analysed the financial models of recent oil and gas developments we would find the key assumptions which underpin the projects would be vastly different to reality. The crystal ball of investment evaluation would benefit from a more powerful way to optimise estimates and assess risk.
A quantum computer offers the ability to perform optimisation calculations not possible with classical computers. The theoretical ability to run infinite parallel processes (as opposed to sequential processes in classical computers) can fundamentally change the optimisation of estimates. Google and NASA were recently able to solve a highly specialised computing problem with a quantum computer 100 million times faster than a classical computer. The power to significantly improve estimation optimisations and thereby reduce risk will help investors achieve a higher degree of confidence and should see levels of investment increase.
Curiosity, creativity and collaboration – creating a digitally integrated supply chain
Authors: Jordan Christopher
Published: June 2017

With the need to extend the life of ageing assets, manage shorter maintenance campaigns and ensure availability of resources, companies are becoming more curious and creative about possible solutions and more willing to collaborate across traditional silos. Oil and gas companies are building more digitally integrated supply chains and are seeing significant results.
When a damaged gasket can cost US$1M/day and create a major safety hazard, even early stage implementation of digital technologies can generate significant improvements. A liquefied natural gas (LNG) plant was curious about what they could achieve through better data integration and alignment. Visualising activity plans and digitally integrating equipment strategies through bill of materials improved the plant’s supply responsiveness, increasing both asset availability and production output by 2%.
Creatively leveraging automation across the supply chain is helping companies become more connected. Starting with advanced analytics, the building blocks for end-to-end solutions are being built. In the near future, predictive part failures data will automatically load into work management processes, maintenance plans will immediately update and the right parts automatically ordered at the right time. Some companies are experimenting with this ‘virtual handshake’ across departments and systems, creating a smarter, faster and more reliable operation. Using both analytics and improved collaboration, one LNG operation has seen a 40% reduction in duplicate parts, a 30% reduction in inventory and an 8% reduction in overall maintenance cost.
Through curiosity, creativity and collaboration across a digitally integrated supply chain, industry organisations can reduce controllable operational cost, making them more reliable and competitive.
The digital workforce – disruptive technologies changing the way work gets done
Authors: Jordan Christopher
Published: June 2017

Digital technologies are extending human capability, creating breakthroughs and disruptive levels of performance. It does this by increasing the information and connectedness of people, equipment, processes and systems. Mobility, analytics, cloud, social and smart objects including phone, watches and glasses, all help personnel accomplish tasks, make better decisions and amplify their performance.
As an example of digital in action, during a planned turnaround one organisation used radio frequency identification (RFID) tags to connect people, equipment and vehicles, combining these with contractor management dashboards that tracked activity. The results were impressive: safety was enhanced and contractor productivity increased by 15%.
But a digital workforce extends beyond RIFD tagging. The end-to-end processing of documents, intelligent work allocation and digitally providing all information required to perform a task is making workforces smarter, faster and more efficient. By consolidating information across operations, work and document management, scheduling and safety systems onto a single platform to provide full visibility, one organisation achieved a 40% savings in the time to allocate work. The company also saw a 10% improvement in tool-time productivity with the right information at the right time. Finally, they are benefitting from immediate and accurate knowledge capture as information is analysed whilst work is being performed.
Harnessing digital technologies requires radical rethinking of traditional approaches to resources, jobs and organisation design. This paper will provide insights and examples of how specific digital technologies are being applied to oil and gas operations to achieve new levels of safety, productivity and cost effectiveness.
Triassic paleogeography and petroleum systems of the North West Shelf, Australia: key insights from a new regional study
Authors: Grahame Jarrad , Cairns Emma , Roy Stephanie
Published: June 2017

CGG Multi-Client & New Ventures, in collaboration with CGG Robertson, has undertaken a new comprehensive study of the Triassic paleogeography and petroleum systems of the North West Shelf (NWS) including the Northern Carnarvon, Roebuck, Browse and Bonaparte basins. The key objectives of the study were to enhance the understanding of the prospectivity of NWS Triassic petroleum systems, develop new paleogeography maps, establish evidence for Triassic marine-derived source rocks and investigate the prospectivity of Late Triassic carbonate reef complexes. The study comprises new biostratigraphic analyses, quantitative evaluation by scanning electron microscopy (QEMSCAN®) analyses, core logging, 1D and 2D modelling of key wells and seismic sections, plate reconstructed paleogeography and play mapping. Of key relevance to this study is the paleo-depositional framework and subsequent structuring of Triassic successions throughout the NWS basins in the context of petroleum system development.
Stakeholder response to abandonment challenges in Australia
Authors: Askew Philip , Lea-Cox Andrew
Published: June 2017

Australia’s early efforts in field abandonment have been limited in comparison to more mature basins, but have proven both complex and high cost, with delayed approvals caused by regulatory uncertainty and social concerns.
Three underlying challenges impact operators and government and require action on both sides to resolve: (1) increasing size and scale of decommissioning liability, (2) limited understanding of challenges and cost drivers, and (3) uncertainty of regulations and taxes.
Abandonment expenditure is expected to accelerate, with most industry companies already active and more companies expected to abandon in the future (e.g. Gippsland, North Carnarvon). Between 2017 and 2030, the overall impact of decommissioning is estimated to be ~US$5.5 billion, with the government taking up to 60% of this cost through taxes and liabilities.
Many companies are looking to upgrade abandonment capabilities and take advantage of new technologies and approaches to reduce costs (although they seem to be struggling to bring programs forward in this period of lower prices). Some companies look to sell assets to late-life operators who tend to be smaller with less abandonment experience and capabilities. In an environment where regulations remain unclear and there is a lack of technology, skills and knowledge around abandonment, the industry is facing unprecedented challenges. Through strategic cost reduction, new technology and operating models, we believe costs could be optimised by a further 10–35%.
The industry, National Offshore Petroleum Safety and Environmental Management Authority (NOPSEMA) and government have started engaging to clarify uncertainty in abandonment regulations. This will require an unbiased process that balances value and risk to all stakeholders and avoids the taxpayer bearing increased costs/rebates from inefficiencies.
Analysis and characterisation of petroleum source rocks in Queensland
Authors: Troup Alison , Gorton Justin
Published: June 2017

A project to improve the understanding of petroleum source rocks across Queensland’s basins was proposed through the Industry Priorities Initiative. The study has identified new source rocks, improved characterisation of known source rocks, and examined their potential as unconventional reservoirs. Round 2 of the project sampled known source rock formations in the Adavale, Bowen, Cooper and Eromanga basins, all with proven petroleum potential. Forty-eight samples from these basins were screened through Rock-Eval and total organic carbon by LECO to determine candidates for further analysis. Pyrolysis gas chromatography was conducted on selected samples (n = 15) to understand the bulk chemical signatures of kerogens with fluids extracted to derive isotopic and biomarker signatures. Organic petrology (n = 11) examined kerogen components and reflectance. Immature samples were analysed for bulk kinetics (n = 10) to determine the stability of kerogens while some were sent for compositional kinetics (n = 7), to predict the gas to oil ratio (GOR) and saturation pressure. Some more mature samples were sent for late gas analysis (n = 6) to understand hydrocarbon generation at later stages of thermal maturation. The results indicate that the marls in the Bury Limestone may have promising potential, that the Permian coals are the principal source rocks in the Cooper and Bowen basins and that the coals and mudstones of the Birkhead Formation have potential to generate. High production index values were noted in the Bury Limestone, as well as coal and mudstone samples from the Cooper and Bowen basins, suggesting that some of these source rocks also have good retention capabilities.
Getting it right the first time in the Ceduna Sub-basin: regional and target depth imaging in a frontier setting
Authors: Koh Weidi
Published: June 2017

The acquisition and depth imaging of almost 20400 km2 of broadband seismic data in the Great Australian Bight has created an excellent dataset fit for quantitative interpretation. This new dataset was derived from a merge of 12400 km2 of 2011 vintage conventional streamer data in an almost seamless manner with 8000 km2 of 2014 vintage dual-sensor streamer data. The Ceduna Sub-basin is the main depocentre of the Bight Basin. It lies adjacent to the continental shelf and slope and is covered by two broad bathymetric terraces in water depths ranging from <200 to >4000 m. A potentially prospective Late Jurassic syn-rift to Late Cretaceous post-rift sedimentary succession (fluvial to paralic sediments) >15 km thick is imaged with remarkable quality and resolution. Features of particular interest include large stacked fan and channel systems, as well as simple, structurally closed formations. Careful survey design and execution optimised efficiency, enabling each survey to be acquired in less than one season. Particular attention was given to amplitude versus offset and phase compliance, including customised flows to overcome a paucity of well control in this frontier area. Optimised preprocessing, velocity model building and survey merging were applied to ensure structural and depth integrity in the final images. Regional and targeted mapping and quantitative interpretation results testify to the value of the multifaceted geophysical and geological disciplines used in the overall project execution.
Porosity and pore size distribution of shales: a case study of the Carynginia Formation, Perth Basin, Western Australia
Authors: Testamanti M. Nadia , Rezaee Reza , Zou Jie
Published: June 2017

The evaluation of the gas storage potential of shale reservoirs requires a good understanding of their pore network. Each of the laboratory techniques used for pore characterisation can be applied to a specific range of pore sizes; but if the lithology of the rock is known, usually one suitable method can be selected to investigate its pore system.
Shales do not fall under any particular lithological classification and can have a wide range of minerals present, so a combination of at least two methods is typically recommended for a better understanding of their pore network. In the laboratory, the Low-Pressure Nitrogen Gas Adsorption (LP-N2-GA) technique is typically used to examine micropores and mesopores, and Mercury Injection Capillary Pressure (MICP) tests can identify pore throats larger than 3 nm. In contrast, a wider range of pore sizes in rock can be screened with Nuclear Magnetic Resonance (NMR), either in laboratory measurements made on cores or through well logging, provided that the pores are saturated with a fluid.
The pore network of a set of shale core samples from the Carynginia Formation was investigated using a combination of laboratory methods. The cores were studied using the NMR, LP-N2-GA and MICP techniques, and the experimental porosity and pore size distribution results are presented. When NMR results were calibrated with MICP or LP-N2-GA measurements, then the pore size distribution of the shale samples studied could be estimated.
Determination of T2 cut-off for shale reservoirs: a case study from the Carynginia formation, Perth Basin, Western Australia
Authors: Testamanti M. Nadia , Rezaee Reza , Yuan Yujie , Pan Dawei
Published: June 2017

Over recent decades, the low-field Nuclear Magnetic Resonance (NMR) method has been consistently used in the petroleum industry for the petrophysical characterisation of conventional reservoirs. Through this non-invasive technique, the porosity, pore size distribution and fluid properties can be determined from the signal emitted by fluids present in the porous media. Transverse relaxation (T2) data, in particular, are one of the most valuable sources of information in an NMR measurement, as the resulting signal decay can be inverted to obtain the T2 distribution of the rock, which can in turn be correlated with porosity and pore size distribution.
The complex pore network of shales, which can have a large portion of pore sizes in the nanopore and mesopore range, restricts the techniques that can be used to investigate their pore structure and porosity. The ability of the NMR technique to detect signals from a wide range of pores has therefore prompted the quest for more standardised interpretation methods suitable for shales.
Using low-field NMR, T2 experiments were performed on shale samples from the Carynginia formation, Perth Basin, at different saturation levels. The shale samples were initially saturated with brine and the T2 spectrum for each sample was obtained. Then, they were placed in a vacuum oven and their weight monitored until a constant value was reached. T2 curves were subsequently obtained for each of the oven-dried samples and a cut-off value for clay-bound water was calculated.
The Great Australian Bight – from AVO prospectivity screening to potentially drillable targets in one of the world's remaining untapped basins
Authors: Rajeswaran Dushyan , Przywara Marcin
Published: June 2017

The Ceduna Sub-basin in Australia’s southern margin offers an untapped opportunity for significant petroleum resource as part of the global exploration portfolio. Analogous to the prolific Niger delta in both size and structural style, this highly-extensional province contains up to 15 km of largely untested post-rift sediments including two widespread Late Cretaceous deltas linked to world-class oil-prone marine Cretaceous source rocks. Regional interpretation of legacy 2D seismic across the Bight Basin brings the sheer scale and structural complexity of this giant Cretaceous depocentre into perspective, but it is only through the detailed analysis of 8001 km2 of dual-sensor towed streamer 3D seismic that its true potential can be quantified. Rigorous phase and amplitude AVO QC of the pre-stack information, coupled with optimised velocity models fed into the depth migration sequence, have ensured amplitude fidelity and phase stability across all offset ranges. This has enabled a systematic and robust exploration workflow of AVO analysis and pre-stack inversion despite limited well data. Numerous dual-sensor case studies have nevertheless demonstrated these Relative Acoustic Impedance and Vp/Vs volumes to be reliably robust for prospect de-risking because of the extended low frequency bandwidth. Frontier screening supported by a partially-automated high-resolution stratigraphic framework has led to the identification of numerous prospects at multiple stratigraphic levels across the survey area. This includes isolation of laterally extensive and vertically amalgamated fan-like structures within the shallow Hammerhead delta using horizon-constrained high-definition spectral decomposition, and the extraction of potential AVO anomalies within the deeper structurally-controlled White Pointer sands draped across large gravity-driven listric growth faults.
Integrated petroleum systems analysis to understand the source of fluids in the Browse Basin, Australia
Authors: Palu Tehani , Hall Lisa , Grosjean Emmanuelle , Edwards Dianne , Rollet Nadege , Higgins Karen , Boreham Christopher , Murray Andrew , Nguyen Duy , Khider Kamal , Buckler Tamara
Published: June 2017

The Browse Basin is located offshore on Australia’s North West Shelf and is a proven hydrocarbon province, hosting gas with associated condensate in an area where oil reserves are typically small. The assessment of a basin’s oil potential traditionally focuses on the presence or absence of oil-prone source rocks. However, light oil can be found in basins where source rocks are gas-prone and the primary hydrocarbon type is gas-condensate. Oil rims form whenever such fluids migrate into reservoirs at pressures less than their dew point (saturation) pressure. By combining petroleum systems analysis with geochemical studies of source rocks and fluids (gases and liquids), four Mesozoic petroleum systems have been identified in the basin. This study applies petroleum systems analysis to understand the source of fluids and their phase behaviour in the Browse Basin. Source rock richness, thickness and quality are mapped from well control. Petroleum systems modelling that integrates source rock property maps, basin-specific kinetics, 1D burial history models and regional 3D surfaces, provides new insights into source rock maturity, generation and expelled fluid composition. The principal source rocks are Early–Middle Jurassic fluvio-deltaic coaly shales and shales within the J10–J20 supersequences (Plover Formation), Middle–Late Jurassic to Early Cretaceous sub-oxic marine shales within the J30–K10 supersequences (Vulcan and Montara formations) and K20–K30 supersequences (Echuca Shoals Formation). These source rocks contain significant contributions of terrestrial organic matter, and within the Caswell Sub-basin, have reached sufficient maturities to have transformed most of the kerogen into hydrocarbons, with the majority of expulsion occurring from the Late Cretaceous until present.
A step change in safety performance through critical control management
Authors: Selleck Roberta
Published: June 2017

The oil and gas construction industry experiences a high rate of unnecessary work-related fatalities. The International Association of Oil and Gas Producers (IOGP) reported 54 fatalities in 40 fatal incidents in 2015. When assessing this against the use of IOGP Life-Saving Rules (LSRs), which contractors are required to adopt, the IOGP found that of the 40 fatal incident descriptions in 2015, at least 73% related to the IOGP LSRs.
A program to apply a critical control management (CCM), or safety cased, approach to fatal hazards was trialled on construction sites in Australia and South Africa ranging from large power station constructions to offshore hook-up and commissioning to brownfields maintenance. The results demonstrated a step change in the safety performance occurred on projects where the CCM program was implemented. These projects have each demonstrated a significant improvement in recordable injuries, increases in hazard reporting and awareness, and almost complete elimination of high-potential incidents.
Further investigation of the reasons for these results is the subject of a PhD project and includes: (1) understanding how the CCM program improves hazard awareness and decision making of frontline supervisors; (2) determining the effects CCM has on the safety climate of the organisation as detailed focus is applied on the effectiveness of controls that drive leadership decisions; and (3) investigating how CCM improves leadership at all levels of the organisation due to better information that allows tangible action to be taken to improve control effectiveness.
This paper describes the progress of CCM program development, details present results and lessons learned, and provides a context for how CCM programs can be implemented in other organisations.
Evolution of the outer basin high, Ceduna Sub-basin, southern Australia
Authors: Cunneen Jane , Grigg Candice , Keating Eoin
Published: June 2017

Recent exploration in the Bight Basin has identified an uplifted area on the outer margin of the Ceduna Shelf, known as the outer basin high. The Tiger Supersequence, a potential source rock, thins onto the uplifted area, so the timing and extent of uplift has implications for petroleum system maturity.
The outer basin high is 15–40 km wide and extends along the south-western flank of the Ceduna Sub-basin, beneath the outer flank of the Ceduna Terrace. Relative uplift of greater than 2000 m occurs within the area. The outer basin underlies a transitional zone of deformation between the extensional faulting and outer fold and thrust regions of the overlying White Pointer and Hammerhead delta systems. Detailed mapping using the recently released Ceduna 3D seismic dataset reveals two main episodes of relative uplift, in the Santonian and again in the Maastrichtian to Eocene. The first phase of relative uplift is associated with thinning of the Tiger Supersequence onto the high. The second phase is identified as a decrease in thickness of the Hammerhead Supersequence overlying the high. The exact timing of this uplift is difficult to constrain due to truncation of the Hammerhead Supersequence by the basin-wide Eocene unconformity, however, estimates of the amount of uplift are based on seismic mapping.
Case study of the effects on coal seam gas well production with installation of well head compression (oil-flooded rotary screw type): early outcomes of an Australian trial of four wells in the Bowen Basin
Authors: Presley Terrance , Kurnia Evilia , Wronski Basia
Published: June 2017

This paper discusses the early outcomes of a trial of well head compression on coal seam gas (CSG) wells to lower surface pressure at the well head. This is a case study of four Johnson Controls Frick rotary screw compressor packages that were installed on CSG wells in an Origin Energy field in the Bowen basin and the early effects of lower well pressures on increased gas production due to the installation of compression.
In mid-2016 Johnson Controls installed four compressor packages on Origin Energy wells with different characteristics (age, flow pressure), with a view of determining uplift of gas flow over the remaining life of the well, as well as operational issues with having well head compression. The expected versus actual uplift is compared for the different wells, with a view of providing some guidance on future potential wells that will benefit from this type of compression. Operational issues, such as effects on water flow, effect of oil and overall design considerations for well head compression, are also discussed.
Maximising ROI through risk based inspection in the CSG industry
Authors: Mills Andrew , Reilly Kelly , Lim Timothy , Strike Glen
Published: June 2017

Australia is forecast to become the world’s largest exporter of liquefied natural gas (LNG) by 2018, and to date, $70 billion has been invested into the Queensland coal seam gas (CSG) industry. These projects consist of tens of thousands of wells, each with a local facility to separate water and gas. From the separation facility, CSG is transported to compression and dehydration stations and water treatment facilities through numerous networks. Spread over an extremely large geographical area, this huge asset count presents a significant challenge to operations and maintenance personnel.
Within Australia, regulation requires operators to inspect new pressure containing assets within the first year of operation. Maintaining compliance with these regulations presents significant costs of finances, time and manpower for operators. Furthermore, travelling to these remote sites for inspection increases the risk of driving accidents, currently the number one safety risk for personnel.
This paper will address these challenges and discuss potential strategies for the optimisation of plant inspection and maintenance management. We will discuss how Wood Group has delivered innovative solutions to operators utilising technical engineering expertise, operational experience, understanding business constraints and delivering maximum return on investment (ROI).
Lithofacies analysis and sequence stratigraphy of the Roseneath-Epsilon-Murteree gas plays in the Cooper Basin, South Australia
Authors: Guo Fengtao , McCabe Peter
Published: June 2017

The early–middle Permian Roseneath-Epsilon-Murteree (REM) strata of the Cooper Basin, South Australia, has conventional and unconventional gas plays. To better understand the sedimentary evolution of the strata, eight key cored wells for the REM in the South Australia were selected and more than 1400 m cores have been characterised to study the lithofacies, facies associations and associated stacking patterns. Twelve lithofacies are identified and further categorised into eight facies associations: (1) open lacustrine, (2) lacustrine shoreface, (3) flood plain/interdistributary bay/channel fill, (4) fluvial channel/distributary channel, (5) crevasse channel/splay/natural levee, (6) distributary mouth bar, (7) prodelta, and (8) mire/swamp.
Cyclic stacking patterns are distinguished both in cores and well logs. X-ray diffraction analysis indicates the lower and middle parts of the Murteree Shale mainly consist of claystone and are characteristic of deep water sediments. The upper Murteree Shale has a larger percentage of silt and sand, which suggests an overall regressive process. The Epsilon Formation displays three stages of deposition: (1) a lower, thin, upward-coarsening package of beach and lacustrine shoreline deposits with a continued regression from the underlying Murteree Shale; (2) a coaly, middle unit deposited by distributary channels, crevasse splays, mires and delta mouth bars; and (3) an upper unit of cyclic coarsening-upward claystone, siltstone and sandstone, deposited in shoreline environments with fluvial modifications. The Roseneath Shale resulted from transgression after deposition of the upper Epsilon Formation with a relatively rapid rise of lake level marked by transgressive lags. A final coarsening-upward sequence of shoreline deposits indicates an ending phase of regression.
Decommissioning – the next Australian oil and gas boom?
Authors: Cullinane Bernadette , Gourvenec Susan
Published: June 2017

In the Oil and Gas Competitiveness Assessment recently published by National Energy Resources Australia (NERA), Australia ranked at the bottom of the group of 30 oil and gas producing nations in abandonment and decommissioning (NERA 2016).
With the recent focus on the massive investment in liquefied natural gas (LNG), it is easy to forget that the Australian oil and gas industry is nearly 100 years old and many assets are reaching the end of their producing life. Liabilities are estimated at more than US$21billion over the next 50 years (Wood Mackenzie 2016a). With nearly 70% of producing assets located offshore, this problem is complex and costly.
The industry must develop strategies to address this looming challenge, however Australia has completed few large-scale decommissioning projects and currently lacks the required experience.
This paper explores how Australia must:

evaluate a range of approaches from complete removal to allowing assets to remain in situ;
develop multi- and interdisciplinary solutions based on the collaborative input of all stakeholders and ocean users to develop a framework suited to our geographic location and environment;
develop fit-for-purpose policies and regulations to support the most appropriate decommissioning framework for Australia, by learning from other countries, while recognising local uniqueness; and
build workforce capability and capacity to support efficient and economical decommissioning activities and stimulate economic growth, which is more challenging than in other regions given our remoteness and high cost structure.

The upcoming decommissioning wave represents a perfect ‘greenfield’ opportunity to apply innovative thinking, new technologies and collaborative approaches as well as an opportunity for Australia to demonstrate global leadership in this inevitable final stage of the lifecycle.