bluuebunny/crossref_metadata_2025 huggingface dataset:
Concurrent in-situ measurement of flow capacity, gas content and saturation
Authors: Morgan Quentin , Pope John , Ramsay Peter
Published: August 2017

A new core-less testing capability has been developed to provide concurrent measurements of coal seam flow capacity and gas content at in-situ conditions. The fluid-based measurement principles are intended to overcome time constraints, accuracy limitations, and cost implications of discrete measurements attributed to traditional ex-situ measurements on core samples. Details of measurement principles, associated enabling technologies, and generic test procedures have been disclosed in a previous publication.
In 2012 a number of field trials were conducted with this new service for both coal mine operators and CSG operators. This peer-reviewed paper will detail pre-job planning, well site execution, and data analysis for one of these trials, which involved testing several seams across two wells, and will illustrate comparison with data acquired using conventional testing techniques from offset wells. This peer-reviewed paper will also highlight key learnings and overall performance, and explain how the learned lessons can be applied to improve testing efficacy and data quality.
Stress-based mathematical model for graded proppant injection in coal bed methane reservoirs
Authors: Keshavarz Alireza , Mobbs Kate , Khanna Aditya , Bedrikovetsky Pavel
Published: August 2017

A technology called graded proppant (propping agent) injection that consists of the injection of proppant particles, with increasing sizes and decreasing concentrations, into a naturally fractured reservoir results in deeper percolation of the particles into the natural fracture system, and thus expansion of the stimulated reservoir area. The placement of graded proppant particles keeps the fractures open, even after pressure decline due to production. There is, therefore, an enhancement in the well productivity. This proposed technology could be used to improve the productivity of CSG wells and other unconventional resources; for example, in shales, tight gas, and geothermal reservoirs.
In this peer-reviewed paper, a mathematical model for well injectivity/productivity was developed for graded particle injection in a vertical well, lying at the centre of a circular drainage area. The model is based on an analytical solution of the quasi 1D problem of coupled axisymmetric fluid flow and geomechanics. Explicit analytical equations were derived for stress, and pressure and permeability distributions, as well as for the well index during injection and production. Results of previous computational fluid dynamic studies were used to determine the hydraulic resistance resulting from proppant plugging in the fractured system.
An optimal stimulation radius was identified, which resulted in the highest increment in the productivity index due to the application of graded proppant injection technology. The model was subsequently used for a sensitivity analysis using field data. The results showed that the productivity index increased more than four times by the application of this technology.
Steps to conducting a valid hydraulic-fracturing laboratory test
Authors: Sarmadivaleh Mohammad , Joodi Bahman , Nabipour Amin , Rasouli Vamegh
Published: August 2017

Several parameters are involved in a hydraulic-fracturing-operation, which is a technique used mainly in tight formations to enhance productivity. Formation properties, state of stresses in the field, injecting fluid characteristics, and pumping rate are among several parameters that can influence the process. Numerical analysis is conventionally run to simulate the hydraulic-fracturing process. Before operating the expensive fracturing job in the field, however, it would be useful to understand the effect of various parameters by conducting physical experiments in the lab. Laboratory experiments are also valuable for validating the numerical simulations. Applying the scaling laws, which are to correspond to the field operation with the test performed in the lab, are necessary to draw valid conclusions from the experiments. Dimensionless parameters are introduced through the scaling laws that are used to scale-down different parameters including the hole size, pump rate and fluid viscosity to that of the lab scale. Sample preparation and following a consistent and correct test procedure in the lab, however, are two other important factors that play a substantial role in obtaining valid results. The focus of this peer-reviewed paper is to address the latter aspect; however, a review of different scaling laws proposed and used will be given.
The results presented in this study are the lab tests conducted using a true triaxial stress cell (TTSC), which allows simulation of hydraulic-fracturing under true field stress conditions where three independent stresses are applied to a cubic rock sample.
Unexpected HTI velocity anisotropy: a wide-azimuth, low fold, 3D seismic processing case study
Authors: Taylor Randall , Cordery Simon , Nixon Sebastian , Driml Karel
Published: August 2017

This case-study demonstrates seismic processing in the presence of Horizontal Transverse Isotropic (HTI) velocity anisotropy encountered in a low-fold land 3D survey in New Zealand. The HTI velocity anisotropy was unexpected, being suspected only after the initial poor stack response compared to vintage 2D sections in the area, and the sparse 3D design made it difficult to identify. The paper shows how anisotropy was singled out from other possible causes, such as geometry errors. We discuss the key steps of the processing flow incorporated to deal with the HTI anisotropy to attain a high quality final processed volume. In particular we show data examples after the application of azimuthally dependant NMO velocities, along with pre-stack HTI migration. Examples are shown which demonstrate the preservation of the HTI anisotropy before and after 5D trace interpolation.
Maps and vertical profiles of 3D attributes are used to demonstrate the magnitude and direction of the HTI velocity field, which varies 5% to 10% between the fast and slow horizontal directions. These observations coincide with the local stress state deduced from borehole break-out studies. We conclude that the fast velocity direction corresponds to the present maximum horizontal stress direction. Finally the paper summarises the implications for processing wide azimuth 3D data in this area and suggests improvements for future 3D survey design.
This paper was originally published in the Proceedings of the 23rd International Geophysical Conference and Exhibition, which was held from 11–14 August 2013 in Melbourne, Australia.
The Ichthys Field: challenges of geological modelling for the field development
Authors: Nakanishi Takeshi , Ando Toshihiko , Beales VIncent , Seth Kapil , Otten Frans , Matsui Hiroyuki
Published: August 2017

Preparation for the Ichthys Field development has been underway since the final investment decision was made in January 2012. The Ichthys Field comprises two reservoirs: the Brewster Member of the Early Cretaceous Upper Vulcan Formation; and the Jurassic Plover Formation. The development will be phased in separate drilling campaigns, commencing with the core area of the Brewster Member reservoir. This reservoir has geological challenges, including:

complexity of porosity and permeability distribution in the generally homogeneous sandstone reservoir; and,
high gas saturation immediately above and below the free water level.
The Ichthys Subsurface team has built geological models of the Brewster Member reservoir. The following methodologies were adopted into the geological models:

broad-band seismic inversion data to distribute reservoir porosity away from well control;
K Nearest Neighbour methodology to predict permeability from logs utilising core measurements;
Cathode-luminescence analysis to understand permeability reduction within the field;
imbibition Sw height functions to model high gas saturation immediately above and below the free water level; and,
scenario-based geological uncertainty modelling.
A series of geological models were utilised to optimise development well locations and to ensure sufficient production from the reservoir.
Enhancement of CBM well fracturing through stimulation of cleat permeability by ultra-fine particle injection
Authors: Keshavarz Alireza , Badalyan Alexander , Carageorgos Themis , Bedrikovetsky Pavel , Johnson Ray
Published: August 2017

Coal permeability declines due to fracture closure during the dewatering stage. A new technique for stimulation of natural coal cleats through ultra-fine and ultra-light high-strength particle injection into a coal fracture system is proposed. Coupling this technique with hydraulic fracturing treatment resulted in particles entering cleats under leak-off conditions.
The following optimal water-based coreflood experimental conditions were determined by applying Derjaguin-Landau-Verwey-Overbeek (DLVO) theory to the interaction between glass particles and the coal matrix: stability of a particle-based suspension (no agglomeration); repulsion between particles and the coal matrix; and, immobilisation of coal natural fines. At these conditions, these particles were placed inside cleats and were not attached to the cleat entrance, leading to less external cake formation; no formation damage due to fines migration was observed. The experimental study was carried out on some bituminous coal samples. Micro-sized glass particles were injected into a coal core at minimum effective stress until core permeability decreased to a value predetermined by a mathematical model. An increase of the effective stress to its maximum value by injection of particle-free water resulted in an approximate three-times increase in coal permeability, when compared to the original value.
The proposed technique can be used for stimulation of a natural fracture network in conventional and unconventional reservoirs, as well as for the enhancement of conductivity of micro-fractures around the hydraulically induced fractures. These particles can be used as a non-damaging leak-off additive during hydraulic fracturing stimulation treatments leading to long-term fracture conductivity.
Assessing the financial value of social licence: a framework and its practical application
Authors: Cooper Susanne , Frew Jon
Published: August 2017

Social licence to operate is of increasing concern to the energy sector generally—and the CSG industry more specifically—with a perception that this industry’s social licence has been eroded in recent years. Many organisations view gaining a social licence as being central to their reputation and business viability. Few organisations, however, have assessed the financial benefit of gaining a social licence, or the cost if it is lost. A framework to assess the financial value of social licence that drew upon multiple disciplines in its development has been developed. This framework has been applied to the CSG industry as well as other industry sectors, generating many practical insights and outcomes. It is an important tool, with sound logic and a clear structure, to identify the full financial costs and benefits of social licence to a project and organisation, and the contributing factors. It has value to boards, project decision-makers and business strategy by providing a visible and tangible expression of social licence in terms relevant to decision-makers that is closely connected with the project phase and material risk. It presents a practical evidence base and dollar value for what is often seen as nebulous, complex and intangible, and therefore easy to marginalise in key decisions. This paper outlines the logic and structure of the framework, and demonstrates its practical application on two major project case studies drawn from the energy and resource extraction sectors.
2013 PESA industry review: exploration
Authors: Johns Rhodri , Despland Patrick
Published: August 2017

Exploration activity in Australia in 2013 occurred across a broad spectrum of conventional and unconventional plays.
Competition for acreage was buoyant with large tracts of key onshore basins either licensed or under application. Offshore, there were new awards on the western Australian margin and in the Bight Basin off SA.
Offshore 3D seismic acquisition was reduced from anomalously high levels in 2012. Onshore 2D seismic acquisition was at historic highs and onshore 3D was the most ever recorded.
Overall drilling levels were maintained despite a decline offshore. Of 13 offshore wells drilled, six were discoveries. Sixty-nine exploration wells (excluding CSG wells) were drilled onshore. Fifty addressed conventional, and 19 were unconventional shale or basin-centered gas targets. Sixty of the 69 wells were drilled in the Cooper/Eromanga Basin where conventional oil and gas exploration yielded 11 oil and six gas discoveries.
Drilling and fraccing campaigns in the Nappamerri Trough unconventional gas plays provided early encouraging results.
213 exploration and appraisal CSG wells were drilled in the CSG basins of Queensland and NSW. In Queensland a record total of 1,317 CSG wells were drilled in fiscal year 2012/2013.
Shale gas exploration activity was increasingly focused on the Palaeozoic and Proterozoic Basins of Western, Central and Northern Australia with major oil and gas companies involved in joint ventures preparing for drilling in 2014. The results of these programmes will have an important bearing on the future direction of exploration in these plays.
Structural architecture and basin evaluation of the North West Shelf
Authors: Pryer Lynn , Blevin Jane , Nelson Gabriel , Sanchez Guillaume , Lee Jen-Deng , Cathro Donna , Graham Rod , Horn Brian
Published: August 2017

The WestraliaSPAN 2D regional program extends across all basins of Australia’s North West Shelf (Carnarvon/Roebuck/Browse/Bonaparte basins) and Arafura regions. The survey is designed with long offset and record length (18 sec) acquisition parameters to image the important deep crustal and sub crustal architecture and depositional systems across this complex margin. The regional program provides unique, state-of-the-art depth imaging of deep-basement rift structures of the Westralian Superbasin, as well as the lower crust and Moho. The survey has multiple transects which cross the transition from continental to oceanic crust, that provide insight into the distribution of volcanics and a possible hyper-extended rift margin. An integrated geological and geophysical interpretation encompasses available well, seismic and potential field data. Gravity models were developed to aid in depth conversion and the structural interpretation of the deep crust and Moho. A comprehensive model of basin formation provides the context for regional correlation of tectonostratigraphic packages throughout these linked basin systems, highlighting pre-Jurassic rift basins and their structural controls. While the North West Shelf, Browse and Bonaparte basins are proven and established hydrocarbon provinces, a future step-change in exploration concepts involves an integrated, margin-scale understanding of these basin systems and their potential resources. Collectively, the new dataset and interpretation will aid explorers in understanding the nature and distribution of key petroleum systems elements (reservoir/source/seal) and processes (heatflow, timing of source maturity, expulsion, migration and entrapment).
The Coniston development: another offshore challenge in Western Australia
Authors: Di Martino Gianluca , Sankoff Roumen , Marshall Craig , Chopra Bobby
Published: August 2017

This extended abstract discusses the key challenges associated with the Coniston development; particular emphasis is on engineering, operations, and project management aspects. The Coniston development will produce oil and gas from the Coniston and Novara hydrocarbon accumulations, located in permit WA-35-L, about 100 km north of Exmouth, in water depths of about 400 m. The Coniston development will consist of a sub-sea tieback to the existing Van Gogh sub-sea infrastructure and the Ningaloo Vision FPSO, currently producing from the Van Gogh Field. The project was sanctioned by Apache in 2011 and will be on production in 2Q 2014. To maximise reservoir exposure, multilateral wells will be drilled, and completed, employing inflow control devices of latest generation and monitoring production with the installation of tracers. To take advantage of project synergies, gas lift will be provided by Van Gogh wells through a dedicated gas production manifold. The Coniston development represents a remarkable multidisciplinary effort to develop a relatively small-size oil reservoir offshore WA. Some of the challenges achieved are the high oil viscosity, the complexity of the engineering to install new sub-sea infrastructure while minimising the impact on Van Gogh production and maximising the synergies of the tie back, the constant increase in drilling and facilities costs while maintaining attractive project economics, and the more stringent regulations environmental permits and the ability to optimise drilling and operation to achieve production as quickly as possible.
Pricing prospects for global LNG and Australian gas markets
Authors: Poynter Fiona
Published: August 2017

Global LNG pricing outlook
Liquidity in the global LNG spot market is increasing and the industry is seeking price diversification in its supply contracts. The rationale for oil linkage is being challenged. Short-term trade now accounts for a quarter of the total market, and the US’ Henry Hub, the UK’s NBP, and global LNG spot indices are all used in LNG price indexation. Growth in LNG supplies, short-term trade, and operational flexibility will drive global price connectivity and increase transparency. The US will begin exporting LNG, tightening the price differential between Atlantic and Pacific basins. The LNG industry will continue to question the validity of oil-price linkage as it seeks a reliable reference capable of reflecting supply and demand fundamentals in the gas markets themselves. It is, however, important to recognise that gas-to-gas pricing will not automatically deliver cheaper LNG than equivalent oil-index formulas.
East coast Australia gas pricing outlook
Dynamics in Australian east coast gas markets are changing rapidly, with LNG at the heart of this revolution. The east coast gas industry seeks a deeper, more liquid and transparent market, while looking to international gas hubs for lessons in boosting market efficiency. The industry must address challenges such as gas storage and pipeline capacity if it is to have the flexibility needed to build a vibrant market. Oil-indexed LNG netback pricing is starting to work its way into east coast gas supply contracts; however, as the European gas industry moves away from oil indexation, Australia’s domestic gas market needs to look at alternative pricing structures.
Legal impacts on gas pricing
Authors: Douglas Chris
Published: August 2017

This extended abstract examines the impact of domestic reservation policies, price review mechanisms and environmental developments on the Australian gas market. The impact of LNG export pricing and the LNG oil-link pricing formula is considered in the context of the impact on domestic Australian pricing. Consideration is given to the role and impact that domestic reservation policies may have on the market going forwards, together with environmental issues arising out of CSG developments. This extended abstract draws conclusions about the future of domestic pricing mechanisms.
The role of geosteering in developing the Pyrenees Field
Authors: Woodall Mark , Skinner Grant , Viandante Mauro , Pontarelli Laura , Kostas Konstantinos , Haynes Elizabeth
Published: August 2017

The Pyrenees Field comprises a series of biodegraded 19° API oil accumulations reservoired in Early Cretaceous sandstones of the Pyrenees Member in the Exmouth Sub-Basin, offshore WA The reservoir comprises excellent quality, poorly consolidated shallow marine to deltaic sands. Variable thickness oil columns (some with associated gas caps), strong bottom water drive, and relatively viscous oil has necessitated the drilling of long (up to 2,000 m) horizontal wells to maximise reservoir exposure while geosteering well to within a few meters of the roof of the reservoir to maximise standoff from the OWCs. The field is covered by excellent quality 3D seismic data; however, pre-drill mapping for well path planning is complicated by the unconformable nature of the top reservoir boundary formed by the sub-cropping Pyrenees Member. Faulting within and localised velocity variations above the reservoir are also a challenge to pre-drill well planning. Cutting-edge geosteering tools have been used to achieve the desired well paths. The tools use azimuthal deep induction resistivity measurements to model and predict reservoir and fluid boundaries, taking advantage of the large resistivity contrasts between the overlying sealing mudstones of the Muderong Formation and the oil (and occasionally gas) bearing Pyrenees reservoir sands. This extended abstract discusses the application of the tools both in pre-drill well path planning and the real-time geosteering operation. Operations are managed between the rig and a sub-surface team located in a dedicated geosteering room onshore. Here real-time data is compared with planned well paths in 3D seismic and geocellular reservoir models and well path adjustments made to optimise final well placement.
Esso Australia 2013 SAFE themes
Authors: Pearson Craig , Robinson David
Published: August 2017

The 2012 APPEA Stand Together for Safety video used a particularly powerful message:

Speak up
Act mindfully
Follow the rules
Get engaged

This aligned with Esso’s global safety learning focus and so it has used the SAFE theme to increase its own workforce engagement. The aim of this initiative was to build and refresh skills and knowledge in the leadership and execution of personal safety expectations using our existing baseline safety tools. A planning workshop was conducted and a small cross-functional team was established to develop the SAFE theme quarterly schedule and materials. The quarterly SAFE theme builds on safety leadership behaviours through the use of existing tools:

First quarter: speak up—focuses on tools for intervention such as approaching others.
Second quarter: act mindfully—hazard identification including StepBack 5x5 and job safety analysis and risk tolerance such as 10 factors influencing risk tolerance.
Third quarter: follow the rules—life saving actions including nine procedural focus areas that save lives
Fourth quarter: get engaged—in-field review such as peer-to-peer observation

Key to the success of the initiative was the significant involvement of senior leadership and first line supervisors. This improved workforce accountability through the application, demonstration, and promotion of safety leadership values. The initiative has resulted in an improvement in our safety performance, and improved communication and alignment across our facilities.
Turning the light on inattention
Authors: Sylvestre Cristian
Published: August 2017

In the past few years, the number of articles and alerts (including some from regulatory authorities) attributing incidents to inattention and/or complacency has increased. Why do so many people still get hurt even though we do so much to try to keep them safe? Most incidents do not happen because the person was not competent, did not know about the hazard or what controls were required. Incidents typically happen because the person was not paying attention at the time; as a result, they get involved with a hazard. Traditional approaches to rectify this focus on:

retraining, in case the problem was a lack of knowledge;
reviewing the decision making framework, in case it was a bad decision or the wrong choice; and/or,
disciplining, in case it was a deliberate act.

The problem of inattention, however, cannot be solved by these approaches. For our inattention, we are accustomed to blaming tiredness, problems at home, outside distractions, and other external factors not in our control. Recent research has identified that more than 95% of personal safety incidents involved inattention (the autopilot mode) leading to an unsafe act. Co-incidentally, the latest neuro-scientific research has discovered that 95% of our actions are subconscious. People can not always control distractions and external factors, but they can influence their subconscious actions (their habits) so what they do in autopilot is the safest thereby preventing many incidents—not just for safety but also for other areas of business.
Exploring for unconventional hydrocarbon plays in the Glyde Basin, Northern Territory, using FALCON® airborne gravity gradiometry (AGG) data
Authors: Kovac Peter , Titus Luke , Cevallos Carlos , Bluett Josh
Published: August 2017

A FALCON® AGG and magnetic survey in the Glyde Sub-basin aims to define the structural pattern to identify unconventional hydrocarbon plays. The survey area consists of variable thick fluvial and lacustrine to shallow marginal marine carbonate-siliciclastic sequences and lesser volcanic rocks. The dominant tectonic feature identified on the AGG data is the Emu Fault Zone: a major structure of the central-southern part of the McArthur Basin. Seismic and surface geology suggest its overall sub-vertical strike-slip nature with positive flower structure geometry. In the north, a regional size pop-up structure, reverse, transpressional and strike-slip faults, and abundant synclines and anticlines identified in the AGG data indicate sinistral transpression. In the south, a transtensional segment of the Emu Fault Zone formed several regularly oriented, fault controlled depocentres. A geological cross-section across the Glyde Sub-basin supported by gravity modelling indicates a system of inverted transtensional faults. Offsets and bifurcations are common, forming local-scale transtensional or transpressional areas. The relationship between dolomitic carbonaceous siltstone, fault-related hydrothermal dolomite (HTD), and the tectonic pattern strongly suggests that the Emu Fault Zone controlled fluid migration and fault-related HTD deposition. Brecciated HTD reservoirs are best developed where a combination of strike-slip movement and extension allowed dolomitising and porosity-generating fluids to migrate along fracture networks, especially in transtensional pull-apart structures, and along the principal faults bounding elevated parts of the basement. This is consistent with the results of the Glyde–1 ST1 exploration well, which drilled 122 m of gas charged dolomitic breccia.
The shifting sands above the oil: commercial and legal tools to manage political risk in emerging markets
Authors: Flynn Christopher
Published: August 2017

An increasing number of Australian resources companies are investing in emerging markets, particularly in Africa. Managing an investment in these countries, and the joint ventures invariably formed in them, is an important part of improving shareholder value, raising capital, and managing political risk. These countries typically take a strategic approach to energy security and resource nationalism rather than the more market-focused approach of western states and companies. While the key risk is expropriation, political risk also presents itself in many other ways. During the long term, an investor needs to minimise the likelihood that it becomes cheaper for a government to breach its obligations to the company than it is to comply with them. Doing that requires several important interrelated protections (both legal and commercial) to minimise political risk and ensure that if expropriation does occur, the investor has maximised its chances of recovering its losses. A range of commercial and legal tools—deployable inside and outside of a country—are available to structure these investments, support operations, and minimise political risk in emerging markets. Drawing on his experience advising on energy and resources projects and transactions in more than 50 countries, author Chris Flynn outlines key legal protections to be sought in any contracts with respect to investments made in these countries. He also discusses useful commercial tools to help align the interests of the company, its local partners, and government.
Back to basics: achieving successful outcomes using structured contracting strategy
Authors: Callaghan Stephen
Published: August 2017

Cost blowouts have been one of the greatest challenges for the Australian gas industry in recent years. To understand these blowouts, it is essential to re-visit some of the basic project and contracting elements such as project timing, overall project cost, market conditions and corporate requirements, and review common pitfalls and misconceptions. Reviewing the Australian gas experience highlights the opportunities and limitations of different contracting strategies and it can identify lessons for future developments. While many organisations seek to transfer risk using hard dollar lump sum contracts with fixed pricing, the frequent failure to appreciate the upfront work required and imposition of unrealistic timeframes—on an organisation and the market—and corporate commitments and culture means this strategy often does not deliver. As the onshore gas industry moves into its next phase of development, ensuring efficient and cost-effective delivery of projects will become increasingly important. Understanding the limitations and strengths of different contracting strategies will be crucial to addressing the industry’s greatest ongoing challenge. Drawing on our involvement in a range of Australian gas projects, including a number of recent CSG projects, this extended abstract examines the spectrum of contracting options available to major gas infrastructure projects and it outlines the key techniques that can be used to ensure contracting strategies support effective project delivery.
Evaluation and application of calcite scale inhibitor in an offshore pH stabilised MEG system—an Australian first
Authors: Backus Farrell , Harvey Evan , Gunn Mike
Published: August 2017

Calcite scale mitigation in pH stabilised MEG systems is a growing concern for the industry as a number of systems are planned for upcoming Australian gas projects.
Issues are insignificant at first gas when water of condensation is present. When formation water production occurs, scale management becomes a critical component of project feasibility. A closed loop pH stabilised MEG regeneration system located in the Otway Basin faced these challenges. Severe calcite scaling in a subsea well, which led to choke failure and MEG system fouling, was successfully controlled by the application of a specific polymeric scale inhibitor.
The operating nature of a pH stabilised closed loop MEG system eliminates conventional scale inhibitor chemistries. Customised polymer chemistries were selected for review predominately due to their ability to persist in a variety of harsh conditions, including the MEG regeneration process.
Technical qualification to validate scale inhibitor functionality was completed using protracted compatibility testing and Dynamic Scale Loop assessment. Evaluation of inhibitor performance and behaviour was accomplished using customised monitoring processes focusing on scale inhibitor detection, identifying measurement interferences, and interaction with precipitated solids.
Field implementation provided excellent results with the inhibitor averting further severe scaling issues, resulting in minimal production system disruption. Fouling of the MEG regeneration system in particular has been minimised, resulting in a reduced frequency and length of cleaning cycles.
This peer-reviewed paper will detail the evaluation, application and monitoring fundamentals when introducing scale inhibitors into pH stabilised MEG systems.
A long history of wet gas pipelines in Victoria
Authors: Henzell Steve
Published: August 2017

Australia's relative isolation and the harsh environment in Bass Strait have led to many innovations in offshore oil and gas developments. The initial developers were moving into frontier territory when Bass Strait was developed, with the harsh sea state and the water depths presenting major challenges.
The original development of Bass Strait in the 1960s was tied to a wet gas pipeline philosophy, which was a novel step-out from normal industry practice. For example, the North Sea developments, which started shortly after Bass Strait, adopted dry gas export pipelines and required substantially larger platforms to process the gas for export.
The cold waters of Bass Strait require an active hydrate management strategy and the success of hydrate inhibitors has been a key element in using wet gas pipelines. The initial development relied on methanol for hydrate inhibition, but this changed to a glycol-based hydrate inhibitor within 10 years of production start-up, due to challenges in the onshore production facilities. The use of mono-ethylene glycol for management of wet gas pipelines was demonstrated in Bass Strait.
The success of the initial developments has given operators the confidence to pursue marginal field developments that rely on wet gas transport to the beach. The Minerva, Casino, Thylacine and Longtom gas field developments in Bass Strait have all adopted the same strategy, in part because of the confidence provided from operating the initial developments for many years.
Water in CSG—a case study in collaborative working
Authors: Greene Dermot
Published: August 2017

Queensland CSG projects require water treatment expertise from clients and consultants to deal with large volumes of associated water.
In this extended abstract experiences and lessons from one of these projects is discussed.
MWH have been working with Origin Energy for the Australia Pacific LNG Water Treatment Facilities project since 2011. A co-located team drove major benefits to Origin, mainly in ensuring a collaborative working culture.
Lessons include MWH adapting to the expectations of oil and gas clients, which differ significantly from municipal clients, thus bridging the cultural gap between oil and gas and water.
Although basic infrastructure does not vary significantly from a normal advanced water treatment plant, aspects such as increased reliability (to ensure gas production to port is not interrupted) drive different requirements.
The key points to be discussed:
Building project culture early through alignment of company cultures, discussing methodologies, expectations, working assumptions and norms to foster a one-team environment, while maintaining alignment across the whole of the project.
Setting BOD, concept, FEED and assurance process expectations early. Taking time to build and review contracting plans, project budgets and schedule, and plans to manage suppliers and contractors.
Developing technical specifications reflecting the correct balance between the water industry and gas industry requirements—per section of facility.
Realising opportunities by setting the correct level of engineering assurance for water treatment plants, as compared to gas facilities.
Aligning operating requirements, specifications, pressure system evaluations and piping and instrumentation diagrams through the design/assurance process.
Decision-making in this complex environment.
Lessons learned from developing offsets in the Brigalow Belt of Queensland
Authors: Bartrim Graeme , Hahn Laura , Blunden Benita , Ewing Chris , Simpson Wendy , Coulson Rob , D'Arcy-Evans Tara , Baker Jaiben
Published: August 2017

Origin Energy—on behalf of the Australia Pacific LNG Project, the upstream tenures for which occupy some 570,000 ha—has established an offsets project in the Brigalow Belt of Queensland.
This belt of Acacia woodland runs between the tropical rainforest of the coast and the semi-arid interior of Queensland, and is one of 15 bio-regions in Queensland. Its reduction to less than 8% of its distribution makes it a significant part of Australia's natural environment.
The offsets project has the aim of re-establishing areas of Brigalow and associated vegetation communities and fauna habitats for impacts on matters of federal or state significance. This should result in a long-term reduction in environmental impacts.
Given the long-term decline in Queensland's biodiversity, such work is vital and its associated challenges—such as gaining long-term access to and protection of appropriate land, comparatively new and evolving regulatory requirements and, at times, working on the edge of scientific knowledge—requires persistence and innovation.
This extended abstract presents valuable lessons learned to help inform future offsetting projects.
More bang for your buck: optimising CSG extraction to achieve increased project value
Authors: Allison Nick
Published: August 2017

Recent challenges within Australia’s oil and gas market have placed increased pressure on Australia’s CSG industry to reel-in burgeoning project costs. In a tight commodity price environment, developments need to extract greater value from projects.
This paper outlines an innovative approach to CSG gathering system design by leveraging the digital oil field approach, utilising technology to rapidly optimise design, reduce design costs and optimise the development processes behind economic resource extraction aimed at ultimately delivering increased project value.
In the past few years a step-change has been made in the optimisation of the engineering design model, with expanded concept level design, FEED-less design, and partially automated detailed design being executed on gathering system projects now being adopted. This was a step towards a fully integrated approach of the digital oil field. Through this process, it has become apparent that this methodology can be extended further through the targeted optimisation of the production model used in the establishment of CSG projects. This will enable increased revenue for a project.
Field production profiles for both gas and water can be developed from preliminary reservoir assessment data. Using cost data for materials and installation, various scenarios can be assessed to optimise production volumes, surface infrastructure configuration, and total volume extracted on a dollar margin per unit energy basis. The optimisation measures explored in this paper are most critical to reservoir locations with a low drainage area per well, where reservoir drainage is maximised by refinement of the configuration of above-ground infrastructure. This has the potential to translate to a more optimised network, and greater profitability in the development of large-scale CSG fields.
Nested approaches to modelling swamp and fluvial channel distribution in the Upper Juandah Member of the Walloon Coal Measures, Surat Basin
Authors: Zhou Fengde , Shields Daren , Tyson Stephen , Esterle Joan
Published: August 2017

Laterally discontinuous coal measures are common in alluvial settings due to interaction with fluvial systems. Under these conditions it is difficult to accurately represent coalbeds and interburden sandstone bodies in static and dynamic models at a regional scale. These challenges are compounded in the Walloon Coal Measures by non-uniform drill spacing, which varies from clustered to sparse and insufficient outcrop exposures available to constrain the correlations.
To address these issues, this study investigates a nested approach to facies modelling of the Upper Juandah Member of the Jurassic Walloon Coal Measures in the Surat Basin, Queensland, which contains some 3,600 wells, of which half were analysed for lithofacies distributions. This approach contrasts the application of truncated Gaussian simulation, object modelling and multiple-point geostatistical simulation.
First, a regional scale structural model was developed based on the correlation of sub units within the basin and the lithofacies were then interpreted from normalised wireline logs. Then geometries of individual facies were defined from two local scale models (~6 × 6 km2) where dense drilling, 3D seismic and paleocurrent analysis data were available to constrain the models. Three training images, generated by object modelling, an analogue of one part of the Ob River, and an interactive method were subsequently used to model primary channels, channels and crevasse splays, respectively. Truncated Gaussian simulation was used in modelling the distribution of marginal and coal swamp. The final model is a combination of the model with primary channels and channels, and the model with marginal and coal swamp.
This approach is the first trial in modelling swamp and channel distributions at a regional scale by integrating data from local models, depositional analogues and paleo-flow interpretation in the Surat Basin.
Recent developments in joint venture jurisprudence
Authors: Brockett Richard
Published: August 2017

It is of vital importance to joint venturers and operators to understand and operate within the boundaries of their contractual framework. A number of recent cases relating to joint venture arrangements have been determined by both Federal and State courts. While each case reviewed is determined on the basis of its underlying facts and circumstances the judgments demonstrate how the courts may interpret and apply standard joint venture provisions. Importantly, the principles enunciated in these judgments may not align with how joint venturers understand their contractual arrangements. This paper reviews recent developments impacting joint ventures and identifies trends that will be relevant for the industry as a whole.
Challenges in applying AS 2885 to aging oil and gas pipelines
Authors: Jones Jeff
Published: August 2017

Oil and gas transmission pipelines in Australia are licensed under state-based pipeline acts and regulations, or a safety case regime for offshore pipelines. Both approaches deal with requirements for the design, construction and operation of a pipeline.
A core requirement of a licensee’s pipeline management system—as required by AS 2885.3 (Operation and Maintenance)— is to maintain a live view of the failure threats to a pipeline. AS 2885 also requires licensees to undertake a regular review of the pipeline safety management study (SMS), to examine the effectiveness of existing threat controls, and to ensure existing and any new threats to the pipeline are being managed to ALARP using the prescribed risk assessment process and societal risk appetite defined in AS 2885.1.
The SMS review is complemented with a similar periodic review of the location class of the pipeline route, often challenged by ever-changing urban development and encroachment. The location class determines design requirements for pipeline wall thickness, external interference protection measures, depth of cover, fracture control, isolation valve spacing and field signage, and is often difficult to comply with or retrofit to existing operational pipelines. Retrospective requirements also require assessment of highconsequence areas for no-rupture and maximum energy discharge rates.
This paper explores the application of the SMS process and the challenges faced by licensees of ageing existing onshore pipelines in complying with AS 2885, and illustrates an array of pragmatic lessons, and the approach taken by the author—in the SMS facilitator role—in assisting licensees to undertake SMS and location class reviews.
Stakeholder trust in the Queensland CSG industry
Authors: Gillespie Nicole , Bond Carol J. , Downs Victoria , Staggs Jonathan
Published: August 2017

Stakeholder trust is pivotal to the social licence to operate and a source of competitive advantage for firms. While managing trust with stakeholders is recognised as a critical management competency and central to delivering coal seam gas (CSG) strategy, to date there has been little examination of stakeholder trust. This research examined the drivers and levels of trust in the CSG companies and industry from the perspective of core CSG stakeholder groups, and identified what stakeholders perceive to be critical for building and maintaining trust in the CSG industry.
With the support of four major CSG companies and the University of Queensland (UQ) Centre for Coal Seam Gas, in-depth interviews were conducted with 145 participants representing five stakeholder groups: landholders, community members, regional leaders, regulators, and employees. An online survey was subsequently developed and completed by 561 CSG stakeholders.
Analysis of the interview data revealed 11 key drivers of stakeholder trust and distrust. Seven drivers focused on how the CSG companies were perceived to operate in regard to: (1) integrity and transparency, (2) communication and interaction, (3) competence and efficiency, (4) community impact and contribution, (5) coexistence with landholders and the community, and having (6) a shared versus divergent identity, and (7) a positive versus negative comparative reputation. Four drivers focused on the broader CSG industry: (8) environmental concerns, (9) governance and regulation, (10) uncertainty and unpredictability of the industry, and (11) the power differential between CSG companies and stakeholders.
Analysis of the survey data revealed significant differences between stakeholder groups in the level and drivers of trust. On average, CSG employees reported high trust, regulators, community and regional leaders reported moderate trust, and landholders reported low trust. In contrast to a minority of employees, the majority of external stakeholders reported concerns over the environmental impacts of CSG and the effectiveness of governance and regulation, and perceived the industry to be unpredictable and too focused on the short term.
Stakeholder recommendations for enhancing trust and strategies for establishing a more resilient and trustworthy industry reputation are identified. Priority areas include: (1) building trust with landholders, (2) increasing the transparency with which companies share information, plans and regulatory compliance, (3) improving the effectiveness of CSG governance and regulation, and (4) addressing environmental concerns.
Diversity, inclusion and CSG: the challenges and the benefits
Authors: Westgate Suzanne
Published: August 2017

Organisations increasingly accept that a genuine commitment to workforce diversity and inclusion improves profitability, reputation and effectiveness. It is also widely accepted that natural CSG projects on the eastern seaboard face increasing challenges from community opposition groups and regulatory change.
Embracing diversity and inclusion in the workplace, and developing CSG projects, both require authentic engagement.
AGL Energy Limited’s (AGL) Inclusion and Diversity Policy recognises that a diverse workforce, with its broad range of experience and perspectives, has a better opportunity to understand and engage in AGL’s customer base and the communities in which it works. AGL’s policy also emphasises how a diverse workforce can facilitate more creative, innovative and effective solutions.
This extended abstract considers how workplace diversity can positively contribute to the development of CSG projects, which must navigate organised community opposition as well as complex regulatory environments. CSG projects, which are typically located in regional areas, can also positively contribute to a more diverse workforce. Provided are examples of situations in which diversity of—and respect for—skills, experience, gender, age, and backgrounds have assisted in achieving successful access negotiations, and enabled authentic engagement with members of the communities in which AGL operates.