bluuebunny/crossref_metadata_2025 huggingface dataset:
Ten years of CO2 storage and operations
Authors: Singh Rajindar , Chable Marc
Published: June 2017

The CO2CRC storage research site, in the Otway Basin (south-west Victoria), focuses on understanding fundamental mechanisms of geological carbon storage resources in saline aquifers. The world-leading project is demonstrating that carbon capture and storage is a technically and environmentally safe way to make deep cuts into global greenhouse gas emissions. Upstream Production Solutions (Upstream PS) are the nominated site manager and have provided ongoing project management, facilities engineering, construction, operations and maintenance services to CO2CRC from the project’s inception.
Over the course of the last 10 years, the project has undergone well and facilities design, and drilling and construction phases, with separate injections of over 80000 tonnes of CO2 rich gas into the formation for research purposes. Unique and dynamic concurrent projects as at the time of writing are: designing a fifth well for the project; commissioning a carbon capture package to provide valuable research data on emerging membrane and adsorption technologies; maintaining and monitoring the overall non-operational site; and planning for a well abandonment.
This sphere of project activity across the whole life cycle requires a robust and holistic focus on management of risk, planning, implementation of right sized solutions and strong stakeholder communications.
This paper details the nature of projects executed and specific challenges encountered and met whilst still following lean practices for a safe yet cost-effective operation for this world leading CO2 research project.
Can a social licence to operate be regained once lost? A case study of the New South Wales coal seam gas industry
Authors: Snashall David , Genter Sabrina
Published: June 2017

The coal seam gas (CSG) industry in New South Wales (NSW) has reached a stalemate, despite a growing demand for domestic gas. The present paper suggests that a key reason for this is the industry’s loss of its social licence to operate, which resulted from a loss in trust and a lack of perceived procedural fairness.
Jemena's perspective on Australian gas market dynamics: a vision of a fiercely competitive market facilitated by an interconnected supply chain
Authors: Green David , Allen Thomas
Published: June 2017

As pipeliners, we take a long-term view of the transformative opportunities facing the Australian gas industry. We believe a market-driven approach will overcome the current challenges around gas price volatility and supply constraints by further developing the missing links that will enable genuine connectedness, greater flexibility and operating synergies across a national gas transportation grid – one that can deliver gas where it is needed most and at the right price.
Looking at mature gas trading environments like the USA provides some aspirational direction in terms of the fluidity of the gas trading environment, where pricing is more dynamic. However, the past and present development opportunities within our own backyard also provide valuable insight. Building the Eastern Gas Pipeline transformed the east coast gas market by introducing a competitive alternative for gas transportation into Sydney and upstream competition between basins. A similar market-led opportunity exists today to build infrastructure connecting Northern Territory gas producers to east coast markets – introducing a competitive alternative for gas transportation and upstream competition between the Beetaloo/McArthur basins and the Surat/Bowen basins. Winning the right to build the Northern Gas Pipeline was an important first step in Jemena realising this vision.
Current regulatory discussions would not be relevant if the industry can shape its own market. Jemena’s northern Australia growth strategy could be the catalyst to resolving these challenges and avoiding further gas constraints or Australian Competition and Consumer Commission interventions seeking to address theoretical issues, rather than solving actual market challenges.
How to effectively manage production facility low-temperature exposure risk
Authors: Bonini Jim
Published: June 2017

A significant risk with any oil and gas production facility is equipment exposure to low temperature fluids, which can lead to brittle fracture, loss of hydrocarbon containment and ignition, with potential consequences including multiple fatalities, major asset damage, production deferment and profound operator reputational harm. Due to the nature of the initiating low-temperature events, which often occur as a result of a sequence of control system, hardware or operational failures, these issues are not always adequately addressed in facility design and operation, which can lead to unacceptable and potentially unacknowledged asset risk exposure. This is especially true in a cost-constrained environment where economic and schedule pressures can drive a leaner approach whereby, for example, traditional design margins are challenged.
Drawing on S2V Consulting’s extensive expertise in this area, this technical paper outlines examples of typical low-temperature exposure mechanisms and key facility risk areas. It highlights why there can be failures in mitigating these risks, both during initial facility design and throughout subsequent operating phase evolution, discusses analytical methods or tools and highlights potential mitigation measures. A structured evaluation process developed by S2V Consulting is presented that can be adopted to effectively safeguard facilities by ensuring these risks are identified, screened, prioritised and managed to ALARP (as low as reasonably practicable). Finally, case studies are presented to provide context to the issue and demonstrate the effective application of the evaluation process to several current Australian production facilities.
Portfolio analysis of petroleum fields and prospects: a robust statistical method
Authors: Vujovic Aleksandar , Gupta Ritu , Smith Gregory C.
Published: June 2017

Portfolio analysis of several prospects, fields or assets is an important part of economic analysis routinely done by most exploration, development and production companies, often for large dollar amounts. Yet the methods used have not changed for decades, most are done in complicated and difficult to audit spreadsheets, and commonly they are not statistically robust, meaning they sometimes give incorrect results. The Curtin University Petroleum Geology Group has an active research program working with the Curtin Statistical Group to improve assessment of petroleum volumetrics, risking, scenario and portfolio analysis. This note provides a simple case study of portfolio analysis using an area in the North West Shelf in which we have quickly mapped several leads, prospects and drilled traps. They span a range of risk outcomes from undrilled to drilled, of which some were dry and some were successful to varying degrees. The results allow us to demonstrate how to calculate and aggregate the volumes and dependencies for each structure, correctly add the results using a new statistical methodology and formulate the aggregated volumetric distribution for the portfolio. This workflow can be used for any portfolio in the petroleum and other industries.
New system for detecting, mapping, monitoring, quantifying and reporting fugitive gas emissions
Authors: Tsai Tracy R. , Du Kendrick , Stavropoulos Bill
Published: June 2017

Coal seam gas (CSG) is an abundant energy source that’s been portrayed as having a lower Greenhouse Gas footprint than coal, but there have been concerns that fugitive emissions may be larger than estimated. Fugitive emissions associated with CSG development are engineered release points (valves and vents etc.) and unintentional equipment leaks. Various gas detection technologies are utilised across the industry that are effective at detecting large emissions sources in close proximity, but they are difficult to scale up to the large size needed for the CSG industry. We’ll present a summary of a trial utilising a new mobile methane detection and emission quantification system: the Picarro EQ (Emissions Quantification). After driving this instrument around CSG infrastructure, Picarro’s cloud-based analytics generate a map of methane measurements and emissions with wind indicators pointing to likely sources. Since all measurements are on a secure cloud-based service, any authorised operator can log into it to run reports and analytics. This system has been used to make measurements in the Barnett Shale, United States. We present results and demonstrate its usage within an operational CSG area to quantify and identify emissions from CSG infrastructure.
Natural catastrophe risk modelling for northwest Australia offshore installations
Authors: Inamura Tomohiko , Lobo Francis , Hirose Rie , Sano Hajime
Published: June 2017

Offshore installations are exposed to several natural hazards. The greatest is severe weather caused by hurricanes and cyclones. Such storms can be devastating, causing widespread damage and financial loss. Insurance companies offer a range of products that insure against potential losses, including physical damage, control of well, sue and labour, removal of wreck, business interruption and liability.
This paper describes the development of the first stochastic natural catastrophe model for the northwest Australian coastal region. It is based on Monte Carlo simulations and uses scientific and engineering knowledge alongside actual insurance claims data to evaluate aggregate storm exposures for the offshore industry in this region.
The model enables quantitative assessment of cyclone risk by developing an improved database through the compilation of available meteorological data. Its development is designed to allow the sustainable and reasonably priced supply of insurance, which is essential to the further extension of exploration and production activities and investment in Australia.
Remote Operations Centres – what next?
Authors: Farrell Bradley
Published: June 2017

Integrated Operations (IO) is a well-established concept in oil and gas. In Australia, upstream oil & gas operators have made significant investments in their local IO capability. For many operators this has meant the creation of a dedicated Remote Operations Centre for their new LNG production assets. By ‘Remote Operations Centre’ (or ‘ROC’) we mean a purpose-built facility where multi-disciplinary teams work together to monitor, support or control production fields and/or assets; with the ROC being geographically distant from those fields/assets. For operators with new LNG facilities, a key challenge has been implementing their ROCs while also focusing on completion of their large complex asset builds. As a consequence, there is an opportunity for further development of Australian ROCs, post start-up, to capture greater value from the new producing assets. For the established LNG operators, rapid advances in collaboration techniques, and in data management and visualisation, present new opportunities to augment their legacy ROCs. In this paper we examine leading practices from ROCs worldwide along with lessons learned that are relevant for Australian operators. We conclude by asking ‘what next?’ for Australian operators.
Enhancing environmental performance during Wheatstone dredging through science and innovation
Authors: Marnane Michael , Elsdon Travis , Rouphael Tony , Pedersen Claus , Peat Kiri , Morgan Ceri
Published: June 2017

Dredging for the Chevron-operated Wheatstone LNG Project, near Onslow, Western Australia, involved movement of approximately 30 Mm3 of material over 23 months to provide safe navigation for LNG export as well as trunkline installation and stabilisation. Dredging was carried out in a sub-tropical, inshore environment near to biological benthic communities including corals, seagrasses, macroalgae and filter feeders, deemed sensitive to elevations in turbidity and/or sedimentation associated with dredging. Science and innovative technology was used to proactively and adaptively management dredging in order to afford a high level of environmental protection. Water quality data was transmitted via satellite to Perth where it was compared, daily, against management triggers derived from scientific analysis of an extensive dataset collected during a previous, nearby, dredging program. Accurate hindcast modelling, combined with MODIS satellite imagery, provided oversight of the extent and cause of observed turbid plumes, while forecast modelling provided predictions of the potential impacts of upcoming dredging activities, allowing for proactive changes to dredging activities to minimise potential impacts. Monitoring of benthic communities was undertaken using remotely operated underwater vehicles (ROVs) and water quality monitoring in the latter part of the program was undertaken using remotely operated Wave Gliders (Liquid Robotics), both of which resulted in significant safety improvements and cost savings and over traditional monitoring methods. Post-dredging surveys of benthic communities indicated that, despite their proximity to dredging activities and the enormity of dredged volumes, no detectable impacts had occurred as a result of dredging.
Floating liquefied natural gas (FLNG): is it still a nice niche?
Authors: Wilkes Martin
Published: June 2017

Two years ago we predicted a bright future for floating liquefied natural gas (FLNG) on the back of a decade of strong growth in the LNG industry. This paper provides an update to that previous paper, examining the impact of both low prices and lower than anticipated growth in the LNG markets on the emerging FLNG technology. After more than a decade of strong growth, the outlook for LNG changed in 2015. Although new markets are emerging, growth in these areas is being offset by contraction in the established markets. New supplies are coming on stream, and adding to an already oversupplied market (at least in the short term). As a result market dynamics are continuing to change, presenting challenges to new supply opportunities. Against this background we have seen several both land based LNG and FLNG projects delayed, deferred or cancelled, but it is notable that the only LNG project outside of the USA to obtain sanction in 2015 was an FLNG project in West Africa (the Perenco Cameroon FLNG project). This presentation reexamines the prospects for FLNG, by: examining how the changes in market dynamics have impacted and will impact the development of FLNG; looking at how the change in price expectations has changed the space in which FLNG must operate; providing an update on current FLNG developments around the world; revisiting historical analogies to FLNG developments; and outlining the impact this has for offshore producers in Australia and the region.
Australian national ocean bottom seismograph fleet advances conventional exploration
Authors: Goncharov Alexey , Malinowski Michal , Sekulic Dejan , Cooper Ashby , Chia Peter , Gavrilov Alexander , Paskos Garrick
Published: June 2017

A fleet of new Australian ocean bottom seismographs (OBSs) have broadband frequency range, and similar instruments are available at only five or six institutions globally. These OBSs are multi-purpose devices able to record passive-source seismic data (earthquakes, ambient noise) as well as active-source (airgun generated) data and, at the same time, to monitor seismic survey noise and whale calls for environmentally responsible exploration. OBS data collected during commercial seismic surveys in Australian waters prove that it is possible to image the velocity distribution of the whole crust and upper mantle from analysis of both reflected and refracted phases generated by an industry-standard broadband airgun array. This means that valuable information on a regional scale can be obtained as a by-product of commercial seismic surveys. Three-component recording capability of OBSs allows analysis of S-waves in addition to the P-waves that are conventionally used in marine reflection surveys.
Woodside Energy Ltd: pioneer in cognitive computing, artificial intelligence and robotics
Authors: Potapinski Russell
Published: June 2017

Cognitive computing is a new disruptive technology with the potential to reshape the oil and gas industry across the entire value chain. For Woodside Energy Ltd (Woodside), embracing this technology is an opportunity to save time, drive efficiency and reduce costs. In 2015, Woodside collaborated with IBM and deployed a cognitive computing system (IBM’s Watson) into its business. The system focuses on capturing the vast proprietary database of knowledge on Woodside’s major capital projects. Today, the Watson proof-of-concept has been successfully deployed by the science function into the business and is now under the care of the projects function. Moreover, it is undergoing continuous advances through further machine learning, additional ingestion of documentation and features linking the cognitive computer system with existing subject matter experts. Given the success of the first pilot program, Woodside is continuing to rapidly leverage cognitive technologies in other areas of the business. In mid-2016, Woodside deployed Watson for drilling events using IBM’s Watson Explorer – Advanced Addition. This program identifies and classifies a wide variety of geological drilling events allowing Woodside’s geoscience team to provide more timely and accurate assessment of potential risks for well design. Woodside continues to develop several other business solutions using these platforms in areas as diverse as continuous improvement, business management, maintenance campaigns, legal advice, general management and robotics.
This presentation shares Woodside’s lessons and insights derived from its journey across multiple forms of cognitive technology and provides insights as to the state-of-the-art and adaptation of these systems to achieve specific goals.
Findings from the Great Australian Bight Research Program – an integrated study of environmental, economic and social values
Authors: Baghurst Ben , Lukatelich Rod , Smith David , Begg Gavin , Lewis Rob , Smith Rochelle
Published: June 2017

The Great Australian Bight Research Program (the Program) has been a 4-year, $20 million research collaboration involving BP, CSIRO, the South Australian Research and Development Institute (SARDI), the University of Adelaide and Flinders University. The Program is generating a whole-of-system understanding of the environment (physical and biological), economic and social values of the region and providing a public information source for all to use. It is one of the few whole-of-system studies ever undertaken in Australian waters and is the first large-scale, integrated study of the Great Australian Bight. Considered prospective for oil and gas, the region is also one of Australia’s most valuable marine ecosystems; supporting globally significant populations of seabirds, marine mammals and diverse and highly endemic benthic assemblages, as well as important fishing, aquaculture and ecotourism industries. The goal of the Program was to obtain information and understanding to better inform the balance of human activity and sustainability in the region. The Program involved more than 100 of Australia’s leading scientists organised around seven themes: Oceanography, Pelagic ecosystem and environmental drivers, Benthic biodiversity, Ecology of iconic species and apex predators, Petroleum geology and geochemistry, Socioeconomic analysis, and Integration and modelling. Through the multidisciplinary approach, supported by two Marine National Facility research voyages in 2013 and 2015 and use of the Integrated Marine Observing System facilities and datasets, the Program is building the first integrated model of the biological and physical systems of the Great Australian Bight.
Tax transparency is not just about tax
Authors: Rintoul Jonathan
Published: June 2017

All Australian corporates with turnover in excess of $100 million have to consider how they will respond to Australia’s Tax Transparency Code (TTC). This is in addition to the Extractive Industries Transparency Initiative and other overseas tax transparency regimes. And, in considering the how, many corporates are seeing the opportunity to showcase the significant contributions their enterprise contributes to the economy which invariably goes beyond the amount of corporate income tax and resources taxes they pay. Once a corporate taxpayer discovers that tax transparency disclosure can actually deliver benefits to their organisation, the questions turn to what to disclose and in what time frame. Ultimately they need to design tax transparency disclosures which are aligned to company objectives, meet mandatory and voluntary requirements, explain the business context around tax payments and clearly communicate the economic benefits of the enterprise to key stakeholders. This requires the input of the tax function, but is as much about the organisation’s reputation in the eyes of its stakeholders and therefore requires an organisation wide view. There is a range of options and it is for each impacted company to assess what they want to achieve from tax transparency ... and it is not just about tax.
Efficient and cost effective power and temperature control is critical to oil and gas operations
Authors: Wheeler Christopher John
Published: June 2017

The availability of reliable, cost effective power and temperature control is critical to all facets of oil and gas operations around the globe. Dropping of global oil prices has had significant effects on long-term liquefied natural gas contracts. Oil and gas producers have experienced a decline in profits, and unprecedented pressure has been put on these companies to remain viable. Many marginal operators have experienced freezing of exploration budgets, delays on future planned expansions and the wind down of non-essential operations.
Herein are four case studies from the oil and gas industry, which highlight several business solutions that assisted companies to stabilise their profits by starting production early, reducing operational down time and assisting process efficiencies.
Gas permeability measurement of shales using the quasi steady-state technique
Authors: Testamanti M. Nadia , Rezaee Reza , Wong Christopher
Published: June 2017

The decline in reserves from conventional reservoirs, paired with the technological advances made in the drilling, stimulation and production areas over the last two decades have placed unconventional reservoirs in the limelight. Shale plays, in particular, have become increasingly attractive prospects and production from these reservoirs has increased significantly during this period.
Most of the petrophysical characterisation techniques routinely used in the laboratory were originally developed for rocks with relatively high porosity and permeability, making some of them unsuitable for tight rocks. Gas permeability measurements in shales can be particularly challenging due to their small pore and pore throat sizes, and even the validity of Darcy’s law under these conditions needs to be evaluated. The steady-state technique is generally unsuitable for measuring gas permeability in shales due to technical limitations of the instruments required, so the quasi steady-state method is proposed as an alternative.
This paper presents the results of gas permeability measurements conducted on two shale core plugs using the quasi steady-state technique. Although the effect of variations in ambient conditions is not usually significant for tests performed on cores from conventional reservoirs, our results indicate that it should not be overlooked when experiments are conducted on shale samples. Furthermore, the length of the core plugs should be minimised to reduce the time required to measure gas permeability.
NSW—Strategic release of exploration areas
Authors: Crosdale Diane
Published: June 2017

In November 2014 the New South Wales (NSW) Government set out a series of actions to pause, reset and restart a sustainable gas industry for NSW. NSW gas demand and supply reinforce the need for the development of a gas industry.
Under this reset, gas exploration areas will be released through the Strategic Release Framework process. The Framework is an independent and transparent process. Utilising geological, economic, environmental and social data including the outcomes of community engagement, areas considered suitable for exploration will be nominated for release. The Framework recognises that there are competing uses for land, and seeks to balance these interests. The Advisory Body, being the independent review body, will conduct these assessments. All release areas will be the subject of a competitive selection process.
Reservoir to market: generating project value by coupling surface facilities with reservoir data in integrated asset modelling
Authors: Stokes Stephen
Published: June 2017

Reservoir to market is a cutting-edge integrated asset modelling (IAM) initiative that is deployed to deliver robust field development and concept design solutions with enhanced project economics. The approach offers the potential to identify supply-chain cost reductions across the full spectrum of upstream developments, from full field development planning to individual equipment item modification. The process offers particular value in Greenfield and Brownfield development planning, in identifying and assessing sensitivity options and in definition of the optimum concept.
Quantifying host nation benefit from LNG developments
Authors: Pulsford Will , Goel Puneet
Published: June 2017

Liquefied natural gas (LNG) project developers invest heavily in evaluating project execution alternatives before deciding to proceed with a development. However, while the technical and economic basis for selecting, for example, a floating (F)LNG concept over an onshore development may be clear for a developer, the host nation which owns the hydrocarbon resources will view the project from a different perspective.
The developer’s project metrics focus on net present value (NPV), return on capital, safety and environmental performance, but the host government’s performance in managing the country’s natural resources is determined by metrics such as tax revenue, employment, industrial development and gross domestic product (GDP) growth. There are areas of clear alignment between the developer and host nation: the more profitable a project is for the developer, the greater the tax revenue from that project. However there are also areas of misalignment and conflict. The issue is brought sharply into focus by cases where FLNG can reduce development costs by replacing an onshore LNG plant with a floating vessel that is often constructed overseas. The host nation must balance the higher tax revenues from the lower cost project against the reduction in local development and employment that would have been stimulated by construction and operation of an onshore LNG plant.
This paper presents a quantitative approach to the assessment of host nation benefit to the national GDP from a natural resource development project. A transparent basis on which to compare the national GDP benefit accruing from competing development concepts, based on internationally recognised metrics and methods, is presented. The technique is applied to a representative comparison of FLNG and onshore LNG development concepts to illustrate the conclusions that can be drawn from its application.
Petroleum migration in the Bight Basin: a fluid inclusion approach to constraining source, composition and timing
Authors: Kempton Richard , Bourdet Julien , Gong Se , Ross Andrew , Pironon Jacques
Published: June 2017

The Bight Basin in southern Australia is a vast under-explored offshore area with promise of, but as of yet, limited proof for hydrocarbons. Fluid inclusions (FIs) offer a unique method to test for petroleum migration, composition and timing, which would otherwise remain hidden in the rocks, and more direct evidence to calibrate basin models. A reconnaissance-scale FI study, using CSIRO’s Grain with Oil Inclusion (GOI™) technique, was undertaken to detect liquid hydrocarbons in Jurassic to Cretaceous sandstones. Oil-bearing, and in some cases gas-rich, inclusions were detected at low abundance, and their presence provides proof of oil generation and migration in the Ceduna Sub-basin. Geochemical fingerprinting of FI oil was undertaken using the Molecular Composition of oil Inclusions (MCI) technique on an intra-Coniacian interval in Gnarlyknots-1A and a Cenomanian interval in Greenly-1. The results show differences in the type of organic matter input, with algal co-sourcing significant for the central Ceduna Sub-basin. The timing of oil migration from pressure-temperature (PT) reconstructions was interpreted in Gnarlyknots-1A, Greenly-1, Duntroon-1 and Potoroo-1. The results indicate oil charge during the Late Cretaceous in the basin depocentres, explained by sediment loading of the Upper Cretaceous succession by the Hammerhead Supersequence and oil, gas-condensate and gas charge to the depocentres and basin margins during the Miocene. The Great Australian Bight Research Program is a collaboration between BP, CSIRO, the South Australian Research and Development Institute (SARDI), the University of Adelaide and Flinders University. The Program aims to provide a whole-of-system understanding of the environmental, economic and social values of the region, providing an information source for all to use.
Achieving tax certainty for oil and gas projects
Authors: Wee Kenneth
Published: June 2017

In recent years, oil and gas companies have been exposed to prolonged periods of volatile oil prices, rising costs and productivity challenges, scarcity and affordability of capital, heightened regulation and accountability and the competition of emerging alternative renewable energy sources. As Australian projects weather the current global oil price and demand–supply dynamics, the future prospects of greenfield and brownfield opportunities will depend on how well proponents can achieve certainty over the geological, geophysical, socioeconomic, operational, political and fiscal aspects affecting their projects.
Establishing certainty of the tax regime and how it will apply over the lifetime of a project is crucial to its after-tax economics and is therefore a central piece of the puzzle that must be solved to secure project investment sanction. This is particularly prudent in an era of increased scrutiny by communities and tax authorities globally on multinationals contributing their fair share of taxes wherever they operate. So, how is tax certainty attained from the outset, and protracted disputation mitigated, in an environment where the tax law is constantly evolving?
Early engagement with the Australian Taxation Office (ATO) is critical to understanding and assuring how the tax law will be interpreted and administered. This paper discusses: (1) best practice ATO engagement avenues for entities seeking to manage the Australian tax profile of oil and gas projects; (2) how to achieve justified trust and be tax-assured; and (3) the types of ATO products best suited to addressing particularly significant tax considerations confronting oil and gas projects.
Improving success rates for Indigenous business engagement
Authors: Saylor Murray , Archbold Deb
Published: June 2017

Although some oil and gas projects have successfully engaged Indigenous businesses in their supply chain, other projects have found this difficult to achieve. Understanding the risk factors in the process of Indigenous engagement and successfully managing those risks creates a positive environment for Indigenous business engagement, one that is much more likely to support long-term success and minimise business and contract failure. Risk management areas to consider include not understanding Traditional Owner community goals and priorities, not assisting communities to build their capabilities and poor communication.
This paper maps these risks and outlines four practical strategies to mitigate these risks: (1) giving local Indigenous businesses the lead time to prepare for work opportunities and build their capabilities; (2) including a mix of large, medium-sized and small local Indigenous businesses in the supply chain; (3) using culturally respectful pathways for Indigenous employment; and (4) maintaining the relationship with Traditional Owner groups.
Managing risks and using these practical approaches will improve and increase Indigenous business engagement in project supply chains.
Polynomial amplitude versus azimuth inversion in horizontally transverse isotropic media, as tested on fractured coal seams in the Surat Basin
Authors: Kremor Joseph , Taylor Randall , Amrouch Khalid
Published: June 2017

A new technique of amplitude versus azimuth (AVAZ) seismic inversion in horizontally transverse isotropic (HTI) media is presented. AVAZ is an effective method of characterising anisotropic variation within individual reflectors as well as characterising fractures. The compressional wave reflectivity equation in HTI media has been reformulated into a parabolic form that allows for fast and efficient inversion. The isotropic component of the azimuthal reflectivity has been separated precisely from the anisotropic component and the anisotropic component has been decoupled exactly into its constituent elliptic and anelliptic components. The exact isotropic, elliptic and anelliptic amplitude versus offset (AVO) gradient equations in HTI media are presented herein and the amount of error associated with previous approximations is also defined under the assumption of weak anisotropy. A method of calculating Thomsen’s weak anisotropy parameters using these AVO gradient terms is then outlined. Compared with the elliptic method, there is reduced error incorporated in the new AVAZ method and the error relationships of this method are compared with the Fourier method.
Data from an open file 3D wide azimuth seismic survey in the Surat Basin were inverted to demonstrate the effectiveness of the techniques which are presented herein. Seismic amplitudes from six azimuthal stacks were extracted over two horizons and inverted around a well where full-wave sonic and density logs were acquired. For both horizons, the error between the inverted anisotropy parameters from seismic and the inverted anisotropy parameters from wire line logs were found to be less than 5% for both horizons.
Nimrod XV230—reflections on leadership, culture and priorities
Authors: Anderson Martin
Published: June 2017

On 2 September 2006 a reconnaissance aircraft Royal Air Force Nimrod XV230 suffered a catastrophic mid-air fire on a mission over Afghanistan, leading to the total loss of the aircraft and the death of all 14 service personnel. This paper summarises key issues from an independent inquiry and challenges the oil and gas industry to reflect on these. The author, a Chartered specialist in human and organisational factors, contributed to The Nimrod Review as a Specialist Inspector with the UK Health and Safety Executive.
Anisotropy parameter inversion from sonic and density logs in horizontally transverse isotropic media
Authors: Kremor Joseph , Amrouch Khalid
Published: June 2017

A methodology of calculating anisotropy parameters in horizontally transverse isotropic (HTI) media using a Backus average-like algorithm is presented herein. Anisotropy parameters in HTI media are calculated by mapping the stiffness parameters that exist in HTI media and vertically transverse isotropic (VTI) media by tilting the Christoffel equations. Fast and slow transverse waves, compressional wave and density logs are used as inputs into the averaging algorithm and, from these, anisotropy parameters are calculated over a predefined averaging window. From the results, the horizontal compressional wave velocity in the direction of the symmetry plane of isotropy can be determined, as can the compressional wave velocity that is perpendicular to the symmetry plane. When the anisotropy is caused by a single set of vertical fractures, these correspond to the directions perpendicular to and parallel to the fracture plane respectively. In cases where the thickness of the bed of interest is thin, a workflow is presented to choose an averaging length that will allow for the calculation of anisotropy parameters and velocities in thin beds. This technique was applied to a coal seam gas well situated in the Surat Basin and anisotropy parameters were calculated over two horizons.
Integrated pre-drill and real-time geomechanical modelling brings significant benefits to deepwater wildcat exploration drilling campaign – a case study
Authors: Asadi M. Sadegh , Ghosh Amitava , Bordoloi Sanjeev , Reese Michael
Published: June 2017

This case study demonstrates the significance of integrated pre-drill geomechanical modelling and real-time monitoring for drilling wildcat exploratory wells in the deepwater settings of an offshore field in South-East Asia. The key challenges in the area include deeper water depths (1.6 km), lack of relevant offset well information and a complex geological setting. In this project, the primary input data for the pre-drill geomechanical model were low resolution 2D seismic velocities derived from an un-calibrated velocity model and petrophysical data from an offset well located in shallow waters, 100 km away from the deepwater prospect.
During pre-drill planning, a contingency casing plan was put in place to consider the uncertainties in the model and cover the worst-case scenario of high pore pressure (PP). To reduce the uncertainty during drilling, the well was monitored in real-time and the pre-drill predictions improved whenever new information or data became available. The objective was to have good data coverage to assist in real-time geomechanical modelling for operational decision making.
Real-time wellbore stability monitoring was carried out by utilising all available drilling and logging data as well as logging while drilling (LWD), pressure measurements and seismic while drilling (SWD) velocities. Wellsite interpretation on cuttings, cavings and formation gases were also integrated into the model predictions. Based on real-time monitoring, pre-drill predictions and model parameters were continuously updated for the next planned section at the end of each section target depth (TD).
Interactive real-time monitoring with continuous pre-drill model updates before drilling the subsequent sections helped to not only deepen the intermediate hole sections, but also to drill efficiently with proper mud weight management and without any significant wellbore instability issues. This integrated workflow helped to successfully drill two exploratory wells, with the major benefit of eliminating the contingency 6ʹʹ slim-hole section.
Monitoring demersal scalefish populations in the Browse Basin region: accounting for spatial variability and detecting change in key fish populations
Authors: Babcock Russ , Lawrence Emma , van der Velde Tonya , Pitcher C. Roland , Tonks Mark , Bessey Cindy , Harvey Euan , Newman Stephen J.
Published: June 2017

One of the objectives of the Applied Research Program (ARP), funded by Shell and the INPEX-operated Ichthys LNG Project, was to establish the basis for evaluating the effects of any potential oil spill from the Prelude or Ichthys fields on populations of commercially important demersal fishes in the Northern Demersal Scalefish Managed Fishery. The ARP has delivered improved baseline understanding of the status and spatial variability in populations of commercially and ecologically important finfish of the Browse Basin region, in the vicinity of the Prelude and Ichthys fields, using both commercial-style fish traps and baited remote underwater videos (BRUVs) as sampling methods. We used available environmental-data layers and fish-distribution data, in combination with modelled plume projections, to design a study such that sites were balanced with respect to fish habitat and likely affected and unaffected zones. The sampling-design employed was statistically effective with power to show changes in fish assemblages, and relative abundance of as little as 30% could be detected with 80% certainty in the main commercial species, goldband snapper (Pristipomoides multidens), using BRUVs. For the second-most important species, red emperor (Lutjanus sebae), a larger decline of 50% would have to occur for this change to be determined with the same level of confidence. Traps were a more powerful tool for sampling L. sebae, allowing a 40% change to be detected; however, for all other species BRUVs were more powerful. Sampling of the demersal-fish assemblages surrounding the Prelude and Ichthys fields by using both fish traps and BRUVs demonstrated the feasibility of detecting change in the relative abundance of the fish assemblage as well as in the key commercial species.
Our focus needs more focus: aligning project risks and expenditure for better environmental outcomes
Authors: Bartrim Graeme , Hahn Laura
Published: June 2017

Project environmental management is becoming increasingly complex and costly. Is the environment best served? Does the community get value? Does the shareholder get value? Will project legacy be land that is stable, uncontaminated, rehabilitated and suitable for future use?
Environmental outcomes and effectiveness will continue to suffer while our focus and scrutiny during the project life cycle is misaligned. The community, government and environmental groups fixate on assessment, approval and conditioning within a maze of requirements (federal, state and local). But are key environmental issues addressed as effectively as possible? How do we prevent short-term administrative urgency and ‘green-tape’ detracting from taking on-ground action to address long-term impacts and liabilities?
This paper explores how better environmental outcomes and greater effectiveness can be achieved with better planning of project expenditure using current tools, by following a more disciplined approach to (i) employ an objective and transparent approach to risk, leading to achievable compliance requirements; (ii) systematically focus on short- and long-term risks using independent inputs; (iii) prioritise timely on-ground actions; and (iv) regularly review and align effort with risk.
The challenges and benefits of such an approach are discussed in relation to three time-consuming environmental activities that span project lifecycle: negotiating regulation, offsetting biodiversity impacts and rehabilitating disturbed areas.
PESA's 50 years—the rise and rise of technology
Authors: Begg John
Published: June 2017

This paper presents an overview of the past 50 years of the Petroleum Exploration Society of Australia (PESA). PESA is a not-for-profit professional association for individuals involved in the oil and gas exploration industry.
Australian onshore petroleum acreage and releases 2017
Authors: Haworth Jeff
Published: June 2017

This paper is a compilation of material from state and territory jurisdictions regarding onshore acreage and its availability for petroleum exploration in 2017. Australian state and territory governments continue to support investment in the petroleum industry through the provision of acreage for exploration, which is promoted nationally and internationally.
Updates are provided on recent upstream developments and government initiatives. Present and future policy directions that relate to onshore petroleum exploration are described, particularly for jurisdictions that are not making land available this year.
When the APPEA conference was last held in Perth, in 2014, the oil price and exploration outlook were very different from today. In 2016, the petroleum industry experienced the full impact of the downturn, with the price for oil reaching a low of under $27 USD/barrel (WTI) early in the year. Several companies departed the onshore, exploration was at a fifteen-year low and much acreage has been surrendered across Australia. However, 2017 is showing signs of improvement with oil prices in the mid-50s and some hope that the industry will turn the corner this year.
Low levels of exploration activity may have implications for future domestic gas supplies, and rising gas prices are of concern to local manufacturing industries and consumers throughout Australia. However, this may present marketing opportunities for successful explorers.
The future is not what it used to be: oil and gas strategies for a carbon-conscious world
Authors: Graham Chris
Published: June 2017

The COP 21 Paris climate deal in December 2015 signalled a landmark shift in a world increasingly conscious of the need to address greenhouse gas emissions. On the day it came into force – 4 November 2016 – 10 of the world’s leading oil and gas companies launched a US$1 billion fund to fast-track the development of low-emission technologies. While admittedly a fraction of their combined annual budgets, it marked a collective and public affirmation of changing attitudes within the industry towards supporting lower-carbon and renewable fuel sources.
The global energy industry is at a turning point. Lower-carbon fuels have overtaken coal and oil in investment and market growth terms. Hydrocarbons will still dominate the future global energy mix, although natural gas and zero-carbon fuels are expected to drive at least 60% of global energy demand growth to 2035.
The new energy landscape will challenge traditional business models in oil and gas production, coal extraction and power utilities. Searching questions can be expected from capital markets in the months and years ahead. Companies could come under pressure to de-risk their existing portfolios and diversify. But judging the pace and scale of transition from old to new will be key.
In this paper, Wood Mackenzie will draw on its global industry expertise and emerging research into how the oil and gas sector can adapt to the increasingly pertinent carbon challenge.
Contrasting oxygen dynamics in Limonium narbonense and Sarcocornia fruticosa during partial and complete submergence
Authors: Pellegrini Elisa , Konnerup Dennis , Winkel Anders , Casolo Valentino , Pedersen Ole
Published: June 2017

Terrestrial saltmarsh plants inhabiting flood-prone habitats undergo recurrent and prolonged flooding driven by tidal regimes. In this study, the role of internal plant aeration in contrasting hypoxic/anoxic conditions during submergence was investigated in the two halophytes Limonium narbonense Mill. and Sarcocornia fruticosa (L.) A.J. Scott. Monitoring of tissue O2 dynamics was performed in shoots and roots using microelectrodes under drained conditions, waterlogging, partial and complete submergence, in light or darkness. For both species, submergence in darkness resulted in significant declines in tissue O2 status and when in light, in rapid O2 increases first in shoot tissues and subsequently in roots. During partial submergence, S. fruticosa benefitted from snorkelling and efficiently transported O2 to roots, whereas the O2 concentration in roots of L. narbonense declined by more than 90%. Significantly thinner leaves and articles were recorded under high degree of flooding stress and both species showed considerably high tissue porosity. The presence of aerenchyma seemed to support internal aeration in S. fruticosa whereas O2 diffusion in L. narbonense seemed impeded, despite the higher porosity (up to 50%). Thus, the results obtained for L. narbonense, being well adapted to flooding, suggests that processes other than internal aeration could be involved in better flooding tolerance e.g. fermentative processes, and that traits resulting in flooding tolerance in plants are not yet fully understood.