bluuebunny/crossref_metadata_2025 huggingface dataset:
Fluorescence application to hydrocarbon monitoring in North West Shelf marine waters
Authors: Harrison Felicity , McAuliffe Riley , Romero Jose , Stubbs Keith , Oldham Carolyn
Published: August 2017

The application of fluorometry to hydrocarbon detection in marine waters is a standard procedure in many parts of the world. This technology is advantageous because spatial and temporal variations in hydrocarbon distributions can be acquired readily and rapidly in a cost-effective manner compared to traditional sampling methods.
Its application to North West Shelf marine waters has been examined through two recent research studies. In the first study, the fluorescent properties of North West Shelf hydrocarbons were compared to those from North America. In general, peak fluorescence of North West Shelf samples are lower than North American and European hydrocarbons. Hence, fluorometer specifications (e.g. excitation and emission wavelengths) need to be tailored for hydrocarbon detection within North West Shelf waters.
The second study measured low background fluorescence of a representative region of the North West Shelf using the fluorometer specifications recommended in the first study. This indicates that background fluorescence is unlikely to affect hydrocarbon detection in the marine waters of the North West Shelf.
These studies support the use of fluorometry as a technique to reliably detect and to monitor unplanned (e.g. spills) and planned (e.g. producted formation water) hydrocarbon discharges across the North West Shelf.
Risk analysis of chemical oil dispersants on the Australian register
Authors: Hook Sharon , Lee Kenneth
Published: August 2017

Following an oil spill at sea, decision-making for the appropriate spill response option(s), including chemical oil dispersant use, is largely based on the results of a net environmental benefit analysis (NEBA). This decision process requires knowledge of the behaviour, transport, fate and effects of the residual oil to minimise the overall environmental impacts of the spill and its subsequent clean-up operations.
In considering oil dispersant use, assessors need information about the influence a chemical dispersant has on the rates of oil biodegradation and whether the dispersant adds to the toxicity of the oil, either by making the oil constituents more bioavailable or through the toxicity of the dispersant itself.
Though many studies have recently been conducted on Corexit, the dispersant used in the US following the Deepwater Horizon oil spill, the chemical formulations of the dispersants for future use in Australia are anticipated to differ, and th s toxicological effects and impacts on biodegradation may be different.
To support NEBA-based decision-making in Australia, there is a need for toxicity studies on the dispersants approved for regional use.
This peer-reviewed paper discusses the important factors for consideration in future toxicity studies such as: the type of oil expected to be spilled; influence on the bioavailability and biodegradation potential of the oil; the sensitivity of regional species at various trophic levels and life stages; and, environmentally relevant exposure conditions.
LNG pricing trends and key considerations
Authors: Rhyn Jacques van , Sadri Janelle
Published: August 2017

Historically, LNG has been sold through long-term contracts with limited flexibility in volume and price. LNG trade patterns have evolved significantly, adding to increased sales of multiple cargoes on the spot market, brokered trades and speculative trading positions being taken up by non-traditional players.
Buyers in the Asia-Pacific region are keen to secure supply for local markets, while Australian producers, particularly subsidiaries of foreign headquartered groups, are under pressure to sell at competitive prices.
From a transfer pricing perspective, the Australian Taxation Office (ATO) has placed increased scrutiny on the commerciality of arrangements, arm’s length outcomes and profit allocations between Australian taxpayers and their international related parties (e.g. marketing and trading hubs).
This extended abstract covers:
factors that could impact on the selection of a price index and the slope or gradient to be applied in pricing formulae;
blended pricing based on an average of different indices, and why pooling and trading may make commercial sense, although revenue authorities may not look favourably upon it;
the importance of the contractual terms, the market situation and the other commercial contract conditions on the pricing of related-party LNG sales; and,
the value in potentially seeking an advanced pricing agreement in a related party LNG pricing context, given the significance of the transactions.

Given the practical and commercial challenges facing the industry and with several projects commencing production in the relatively near future, this is very topical. The authors use case studies to illustrate the key concepts.
Setting up for success for mobilisation to major hazard facilities—a contractor's perspective
Authors: Simpson Melinda , Tooley Neil
Published: August 2017

The challenges for a contractor to mobilise to a major hazard facility come from differences in expectations between stakeholders, gaps and inconsistencies between health, safety and environment (HSE) management systems, and the logistical challenges of initial training and competency verification.
Differences in expectations can arise between the corporate office and site or also between various functional silos. HSE management system challenges manifest in the detailed procedures when the safety case is in operation.
Training and competency assessment is an ongoing requirement, but the initial demand at first mobilisation creates a one-off logistical burden.
The steps to lessen the impact of these challenges and to enable a successful outcome include:

alignment workshops with customers and other stakeholders to create a shared safety culture and expectations of management systems;
joint HSE management system gap analysis and risk workshops; early interface meetings with stakeholders; and,
requirements having a comprehensive definition and pre-planning to deliver best practice.

A successful mobilisation is characterised by the alignment of systems, improvements made during the alignment process by delivering best practice, meeting all HSE obligations for employees (including seconded personnel and sub-contractors), bridging the gap with sub-contractor management when implementing the safety case, and having all personnel trained before mobilisation.
This extended abstract draws on lessons from recent real-world experience and offers a framework to overcome challenges a contractor can encounter, and sets up successful mobilisation for a major hazard facility.
Aboriginal employment—Chevron's journey
Authors: Smith Camis
Published: August 2017

Advancing Aboriginal participation in the workplace comes with its challenges, and those experienced in the oil and gas industry are unique. Barriers to participation need to be regularly evaluated and addressed for success.
Although Chevron Australia's focus on Aboriginal employment is fairly recent, it receives strong internal support from senior and corporate leadership. It will be important in the future to further this commitment and build ownership throughout the organisation to achieve long-term results and meet business needs and skills gaps.
Camis Smith, Chevron Australia's Aboriginal Employment Strategy Manager, will share Chevron's experiences, lessons and challenges in advancing Aboriginal participation in the workplace, and reinforce its reputation as an employer of choice.
Chevron is one of the world's leading integrated energy companies and through its Australian subsidiaries, has been present in Australia for more than 60 years. With the ingenuity and commitment of more than 4,000 people, Chevron Australia leads the development of the Gorgon and Wheatstone natural gas projects, and has been operating Australia's largest onshore oilfield on Barrow Island for more than 45 years.
Bias blockers and resilience builders
Authors: Coventry Petrina
Published: August 2017

This extended abstract shares research factors that affect gender equity in the workplace, along with subsequent workplace interventions that have been trialed at Santos to address the research findings.
A collaborative initiative between several leading universities and companies across a range of industries was established to identify challenges associated with gender representation in the workforce. A number of key research areas were focused on, including bias and its effects on gender equity, resilience in the workplace, and factors that affect retention and attrition of women in the workplace.
Findings

Unconscious and conscious bias needs to be tackled directly and through open intervention. Bias in manifested in judgments and decision-making that affect women's working conditions. Removing biased decision-making through awareness programs, education and direct challenge has a positive impact on diversity and productivity.
Resilience builders can differ by gender. Interventions in the workplace to build resilience for women need to include confidence building. Successful women can suffer confidence crises as often as less successful women. Women are more likely to establish the confidence needed to be resilient in organisations when there is a culture of psychological flexibility.

This extended abstract will share the application of the research findings to the Santos workplace. For example, how decision making and bias training at Santos has assisted a broad range of disciplines, and what effect resilience-building strategies have had on productivity and culture.
Unconventional gas prospectivity of the Cooper Basin
Authors: Hall Lisa , Hill Tony , Wang Liuqi , Edwards Dianne , Kuske Tehani , Troup Alison , Boreham Chris
Published: August 2017

The Cooper Basin is an Upper Carboniferous–Middle Triassic intracratonic basin in northeast SA and southwest Queensland. The basin is Australia's premier onshore hydrocarbon-producing province and is nationally significant due to its provision of domestic gas for the east coast gas market.
Exploration activity in the region has recently expanded with numerous explorers pursuing newly identified unconventional hydrocarbon plays. While conventional gas and oil prospects can usually be identified by 3D seismic, the definition and extent of the undiscovered unconventional gas resources in the basin remain poorly understood.
This extended abstract reviews the hydrocarbon prospectivity of the Cooper Basin with a focus on unconventional gas resources. Regional basin architecture, characterised through source rock distribution and quality, demonstrates the abundance of viable source rocks across the basin. Petroleum system modelling, incorporating new compositional kinetics, source quality and total organic carbon (TOC) map, highlight the variability in burial, thermal and hydrocarbon generation histories between depocentres.
The study documents the extent of a number of unconventional gas play types, including the extensive basin-centred and tight gas accumulations in the Gidgealpa Group, deep-dry coal gas associated with the Patchawarra and Toolachee formations, as well as the less extensive shale gas plays in the Murteree and Roseneath shales.
Formation evaluation case study: Glyde unconventional Middle Proterozoic play in the McArthur Basin, northern Australia
Authors: Croon Marcel , Bluett Joshua , Titus Luke , Johnson Raymond
Published: August 2017

The Glyde–1 and Glyde Sidetrack–1 wells were drilled by Armour Energy in the Glyde Sub-basin of the McArthur Basin, NT, Australia in August 2012. This program was to evaluate the unconventional hydrocarbon potential of the Barney Creek Shale source rock and the conventional potential of the Coxco Dolomite of the McArthur Group.
The Glyde wells discovered gas in both formations. Transtensional faults in this region allowed to form a series of fault-bounded depocentres. The target gas source of the Glyde discovery is located in 1640 Ma organic-rich black shales of the Barney Creek Formation.
Weatherford was contracted to acquire both vertical and lateral advanced log suites and perform subsequent log interpretation to constrain the in situ minimum and maximum horizontal stress regimes to assist with maximising gas production from future lateral placement pilot programs in the Coxco Hydrothermal Dolomite (HTD) Play.
Two stratigraphic and structural domains were defined by the observed features in the image log data; a dolostone dominated, fractured strata below an erosional surface. Above this stratigraphic timeline is a monotonous package of laminated, lower-energy Barney Creek Formation sediments.
Observed changes in azimuths and dips of the measured beddings suggest a phase of compression after deposition of the Barney Creek Formation, resulting in gentle folding of the formations. The porous gas-charged HTD play is drilled in top of the anticline, which is further characterised by a significant number of conductive fractures, likely indicative of open fractures.
Portfolio management: a strategic approach to achieving corporate targets
Authors: Rodger Angus
Published: August 2017

Energy companies set themselves measurable targets across a number of metrics, which allow investors to rank and benchmark their performance. This can include exploration success, reserve growth, capital expenditure, production and revenues. But the oil and gas business is inherently high-risk.
On a project basis, companies may find it difficult to meet their corporate targets, for factors inside or outside of their control.
Portfolio management can help companies achieve all their goals—earnings, production and reserve replacements—in the most efficient manner; whatever the external market conditions.
There is no one correct approach to portfolio management and evidence suggests that companies extol the virtues of the core principles but rarely adhere to them. In boom years, more capital was allocated to riskier projects, and in bust years, budgets and headcounts were slashed. Conversely, inefficient portfolio management can both destroy value and increase risk.
This industry is presently in a period of cautious capital allocation, with a greater focus on upstream returns, project screening, asset sales and a retreat to company heartlands; particularly in North America.
But are many of these decisions based on markets trends? And are not portfolio-driven? This extended abstract offers a commercial perspective on portfolio management by companies in the region, in light of recent trends, and includes case studies of successful portfolio-based decisions.
Safeguarding the future
Authors: Morgan Shaughn
Published: August 2017

The present climate of coal seam gas (CSG) production in east coast Australia illustrates the importance of consultation and engagement with the government and stakeholders. This extends particularly to agricultural and community groups, and the impact they have on government policy decisions and in some instances, knee-jerk reactions based on emotion rather than science.
Farmers are (and have been) strong environmental managers who want to ensure that the protection of prime agricultural land is safeguarded for future generations—however, so do petroleum companies and working side-by-side for a successful outcome is achievable. For instance, AGL Energy has invested in the agricultural sector from vineyards to growing cattle, allowing the company to engage in the sector directly. On the ground early engagement strategies increasingly need to be implemented with agriculture, which reassures the government and provides a win-win outcome by diffusing anti-groups and community divisions by bringing opportunities for sustainable economic benefit.
One of the critical questions is how can this be done successfully without it being seen by the government and community as corporate spin. Particular reference will be made to NSW and the relationship that AGL Energy has built with agriculture organisations, such as Dairy Connect NSW and community groups such as Advance Gloucester.
This extended abstract will illustrate that the opportunities for growth for CSG, agriculture and the community are only limited by narrow views of what is achievable and what is drawn from real-life experiences from AGL Energy operations in NSW.
Subtle oil fields along the Western Flank of the Cooper/Eromanga petroleum system
Authors: Sales Mark , Altmann Malcolm , Buick Glen , Dowling Claire , Bourne John , Bennett Alexandra
Published: August 2017

Oil production from Cooper/Eromanga started in 1978, peaked in the 1980s and began a steady decline. Oil production from the Western Flank commenced in 2002 and has steadily increased. In the year until July 2014, a total of 8.6 million BBL of oil was produced from 16 active fields along the Western Flank, bringing the cumulative total to 24 million BBL. Western Flank oil has underpinned a ten-fold growth in market capitalisation in four listed Australian companies: Beach Energy, Drillsearch Ltd, Senex Energy and Cooper Energy.
Two sandstone plays dominate the Western Flank petroleum geology: the Namur Sandstone low-relief structural play and the mid-Birkhead stratigraphic play. The use of 3D seismic has improved the definition of both plays, increased exploration success and optimised field appraisal and development drilling.
Success rates have improved despite most Namur structural closures being close to the resolution margin for depth conversions (less than 8 m). Seismic attribute mapping is being refined in the more difficult search for mid-Birkhead stratigraphic traps with recent exploration discoveries indicating improved success.
Reservoir properties in the Namur are excellent with multi-Darcy permeability, unlimited aquifer strength, low gas/oil ratio (GOR) and low residual oil saturation. This combination leads to an oil recovery factor greater than 75%. Initial free-flow production rates commonly exceed 6,000 BBL per a day.
The mid-Birkhead reservoir is also of high quality but the lack of a strong aquifer drive reduces primary recovery.
New and re-processed 3D seismic and water-flood projects are expected to drive further discoveries, reserve and production growth.
Shale gas resource assessment in the Merlinleigh Sub-basin, Carnarvon Basin
Authors: Wong Joanna , Bahar Mohammad
Published: August 2017

The recent shale gas developments in the US have encouraged exploration for shale gas resource in WA. In the largely unexplored Carnarvon Basin, the Merlinleigh Sub-basin is predominately of Permian strata and has been shown to contain high-quality gas-prone source rocks from geochemical data.
Three main potential shale layers, the Gneudna Formation, Wooramel Group and the Byro Group, were identified based on the shale ranking parameters. Geochemical data was collected and analysed for the type of kerogen, total organic content (TOC), generation potential and thermal maturity.
These parameters enabled a gas-in-place resource estimation to be made for each of the formations. The TOC data from various wells were validated by using petrophysical logs and the ÎlogR method. In comparison with the geochemical data, both values produced a good match, validating both sets of data.
The three layers were ranked according to their geochemical parameters and any petrophysical or geomechanical characteristics. It was identified that the Wooramel Group contains the best quality source rocks, followed by the Byro Group. The Gneudna Formation was found to have poor quality source rocks.
The Monte Carlo method by Crystal Ball was selected to estimate the probabilistic resources of these three layers. According to the P50 estimations, the Byro Group, Wooramel Group and the Gneudna Formation contained resources of 51.6 tcf, 40.1 tcf and 1.4 tcf, respectively.
Regional oil wildlife response capability in northwest Australia—a collaborative approach by oil and gas operators and agencies
Authors: Harrison Gregory , Quinn Nick , Best Andrew
Published: August 2017

In January 2012, the National Offshore Petroleum Safety and Environmental Authority (NOPSEMA) took over the environmental assessment of environmental plans (EP) and oil spill contingency plans (OSCP) in Australia's Commonwealth waters. The requirement to demonstrate capability highlighted several areas of improvement to provide an effective oiled wildlife response (OWLR). An OWL working group was established by several operators with the initial agreement to engage the Australian Marine Oil Spill Centre (AMOSC) as the response agency. The working group of operators has now established an OWLR Plan that was developed in collaboration with AMOSC and the Department of Parks and Wildlife and has provided an industry and government agency coordinated approach to OWLR for the first time.
Circumnavigating offshore resources worker visas—understanding the opportunities and challenges
Authors: Parcell Wayne
Published: August 2017

On 29 June 2013, the Australian government amended the Migration Act 1958 to extend the definition of the migration zone and prospectively introduce a new visa pathway specific to offshore resources activities. The amendment required all foreign workers participating in or supporting an offshore resources activity in the maritime zone to hold a visa with effect from 30 June 2014.
After consultation with stakeholders, the present government introduced migration regulations on 30 June 2014, prescribing three types of temporary work visas that foreign workers can hold to lawfully participate in or support an offshore resources activity. The government relied on the existing visa regime, including the subclass 988 Maritime Crew visa. On 16 July 2014, the senate disallowed these regulations.
To restore certainty to the offshore resources industry, the Assistant Minister for Immigration and Border Protection issued a determination on 17 July 2014, effectively removing offshore resources activities from the scope of the Migration Act 1958, therefore enabling foreigners to perform such activities without a visa.
The Maritime Union of Australia and the Australian Maritime Officers Union are challenging the decision in the Full Federal Court. The appeals will be heard together in Sydney, during February and March 2015.
The author will discuss the latest insights into the visa framework and the direction of this issue as parties strive for differing outcomes. The ongoing uncertainty concerns employers who seek clarity of this issue to meet workforce planning and supply chain management priorities.
Magnetotelluric monitoring of coal seam gas depressurisation
Authors: Rees Nigel , Heinson Graham , Krieger Lars , Boren Goran , Conway Dennis , Carter Simon , Rugari Joseph , Putland Oliver , Schnaidt Sebastian
Published: August 2017

The depressurisation of coal seam gas (CSG) formations causes in-situ fluids to migrate through pores and fractures in the earth. The removal of large volumes of water from coal seams has the potential to affect water table levels and groundwater flow in surrounding aquifer systems. Magnetotellurics (MT) is a passive electromagnetic technique that uses the natural fluctuations of electric and magnetic fields at the Earth’s surface to determine the Earth’s conductivity structure. The bulk movement of fluids during CSG depressurisation causes a conductivity change in the subsurface and this change can be monitored using MT.
An electromagnetic survey was conducted at a CSG production scientific test site. Electric and magnetic field instruments were deployed, measuring continuously at 651 Hz across three months. New processing software was developed to generate MT responses in the bandwidth of 100–0.1 Hz across the experiment.
The theory of monitoring subsurface fluid movement using MT is presented, as well as instrumentation and a case study to demonstrate the potential of the magnetotelluric method. Results from this approach can provide an inexpensive means of monitoring CSG depressurisation, as well as an improved understanding of the potential impacts on the subsurface environment during CSG production.
Normal fault growth and segment linkage in a gravitationally detached delta system: evidence from 3D seismic reflection data from the Ceduna Sub-basin, Great Australian Bight
Authors: Robson Alexander , King Rosalind , Holford Simon
Published: August 2017

The authors used three-dimensional (3D) seismic reflection data from the central Ceduna Sub-Basin, Australia, to establish the structural evolution of a linked normal fault assemblage at the extensional top of a gravitationally driven delta system.
The fault assemblage presented is decoupled at the base of a marine mud from the late Albian age. Strike-linkage has created a northwest–southeast oriented assemblage of normal fault segments and dip-linkage through Santonian strata, which connects a post-Santonian normal fault system to a Cenomanian-Santonian listric fault system.
Cenomanian-Santonian fault growth is on the kilometre scale and builds an underlying structural grain, defining the geometry of the post-Santonian fault system.
A fault plane dip-angle model has been created and established through simplistic depth conversion. This converts throw into fault plane dip-slip displacement, incorporating increasing heave of a listric fault and decreasing in dip-angle with depth. The analysis constrains fault growth into six evolutionary stages:

early Cenomanian nucleation and radial growth of isolated fault segments;
linkage of fault segments by the latest Cenomanian;
latest Santonian Cessation of fault growth;
erosion and heavy incision during the continental break-up of Australia and Antarctica (c. 83 Ma);
vertically independent nucleation of the post-Santonian fault segments with rapid length establishment before significant displacement accumulation; and,
continued displacement into the Cenozoic.

The structural evolution of this fault system is compatible with the isolated fault model and segmented coherent fault model, indicating that these fault growth models do not need to be mutually exclusive to the growth of normal fault assemblages.
Rock physics modelling and analysis of time-lapse seismic response in the Pyrenees Field, offshore Western Australia
Authors: Kuzmin Stanislav , Florez Mauricio , Duncan Guy , Kostas Konstantinos
Published: August 2017

Rock physics modelling of the time-lapse seismic response of the Pyrenees Field was carried out to evaluate the feasibility of monitoring reservoir drainage and performance. Initially, the purpose of 4D seismic was to monitor the upward displacement of the oil-water contact. It was recognised that the likelihood of gas breakout imposed a significant risk to the feasibility of monitoring the oil-water contact. Models for different scenarios were used to assess this uncertainty and demonstrated that, in either case, an observable change in seismic properties would occur, providing technical support for 4D seismic acquisition.
The monitor seismic survey acquired in 2013, showed detectable changes in both interval velocity and reflectivity that was associated with gas coming out of solution in the reservoir, where depletion occurred below the bubble point. This agrees with pre-acquisition predictions based on rock physics modelling. Additional rock physics analysis was carried out to calibrate the observed 4D response to changes in both fluid saturation and effective stress.
South West Hub CCS Project: Lessons to be learned from the 2014 3D seismic survey
Authors: Burke Martin , Gent Dominique Van
Published: August 2017

The South West Hub (SWH) project is Australia's first carbon capture and storage (CCS) flagship project. Managed by the WA government's Department of Mines and Petroleum (DMP), the SWH is assessing the geological properties of a proposed CO2storage site in the southwest of WA to determine its feasibility. This includes collating detailed geological information, partnering with researchers, acquiring baseline data, consulting with communities and stakeholders, and negotiating land access.
Recent activities have included a 2D seismic survey in 2011, drilling of a stratigraphic well (Harvey–1) in 2012 and a comprehensive (115 km2) 3D seismic survey in 2014.
A further drilling program is planned for the fourth quarter of 2014 until the first quarter of 2015.
The 2014 3D seismic survey has been described as one of the most complex land-based seismic surveys conducted in Australia due to environmental factors, and competing land-use and land-access constraints.
This extended abstract reviews the recent 3D seismic survey, including the development of the project's scope and procurement processes through to community engagement and implementation, and outlines how the lessons are being incorporated into the upcoming drilling program.
It will also discuss legacy issues that have impacted on community attitudes and confidence, and the challenges of working with potentially hostile communities, and also demonstrate how the project adopted and adapted best practice engagement guidelines and toolkits for CCS projects to achieve successful outcomes.
A numerical assessment of the effect of particle size distribution and operation parameters on sand retention over sand screens
Authors: Feng Yuqing , Choi Xavier , Wu Bailin , Wang Qinggong , Wong Chong Yau , Lim Seng , Madon Bahrom , Jadid Maharon , Johar Zurita , Zamberi Amir , Shaffee Amira
Published: August 2017

Sand screens are often installed in sanding prone wellbores to control sand production. A selection of optimal sand screen apertures is required to minimise sand production and maximise fluid production. This has been accomplished historically on empirical correlations, rules of thumb and laboratory sand retention experiments. These methodologies have a number of limitations that can lead to different screen types and sub-optimal screen apertures to be selected.
Using discrete element models (DEMs), many design/operating parameters similar to a specific wellbore condition can be simulated and tested in parallel. Most importantly, the detailed particle scale information helps to give a detailed understanding of the underlying mechanisms controlling the sand retention process.
This extended abstract presents an investigation of the sand production problem from wire wrapped screens and slotted liners through the use of a DEM for the solid flow with fluid flow coupling using computational fluid dynamics (CFD).
Information about particle sizes and distributions incorporated in the DEM model are based on measurement data from reservoir sands. The focus is on the effect of particle size distributions, particle concentration, and the slot width on sand retention across a slotted sand screen.
Changing the path of mini-DST through an advanced wireline formation testing technique: first application in the Asia Pacific
Authors: Firinu Mauro , Derrij Joseph , Harfoushian Jack H.
Published: August 2017

As the oil and gas industry moves towards new ventures and remote locations, possibly in more challenging reservoirs and in high-cost, high-risk environments, a cost-effective formation testing method is fundamental to assess new findings and proper decision making. Despite its ability to provide precise pressure profiles and multiple samples obtained along reservoir sections, wireline formation testing is generally seen as complementary to extensive well test operations.
Determination of reservoir viability with wireline testers is often considered only indicative of reservoir productivity, while testing techniques through straddle packers are perceived as not totally risk free. Information obtained from a well test often depends on the reservoir type. If most of the heterogeneous carbonate reservoir warrants comprehensive testing to evaluate productivity through natural fractures, evaluation of homogeneous sandstone is generally an assessment of matrix permeability.
An advanced formation testing technique was used for the first time in a 12.25-inch bore hole in the Asia Pacific region. An effective mini-DST was carried out by delivering an inflow performance relationship (IPR) consistent with the known production behaviour of the Laminaria Formation in the Kitan oil field in a cost-effective manner compared to the traditional straddle packer technique. In addition, this case study points out that under certain circumstances, mini-DST results from a specific interval of the reservoir can be scaled up to the whole reservoir under investigation, making this technique potentially an alternative to a full well-testing program, when rig costs or environmental constraints often make such a procedure prohibitive.
Improved reliability in IsoTube sampling using an IsoTube Autoloader
Authors: Mitchell Ian , Bamborough Edward , Heard Stephanie
Published: August 2017

Accurate and consistent sampling of reservoir gases is a critical element of any formation evaluation program. Traditionally, this has been achieved while drilling using IsoTubes collected with a manual manifold. This conventional method is reliant on personnel at the rig site physically taking the sample at the required interval or threshold and so is susceptible to human error or oversight. The IsoTube AutoLoader is a new automated system that is driven by a web application running on a state-of-the-art embedded computer. The automation process reduces the risk of human error and avoids potential missed data while also offering a better quality data set with less contamination. This system improves the quality and reliability of data collection to assist with formation evaluations.
New method of controlling excessive water production in wells using induced formation damage
Authors: Zeinijahromi Abbas , Bedrikovetski Pavel
Published: August 2017

Excessive water production is a major factor in reduced well productivity. This can result from water channelling from the water table to the well through natural fractures or faults, water breakthrough in high permeability zones, or water coning.
The use of foams or gels for controlling water production through high-permeable layers has been tested successfully in several field cases.
A large treatment volume, however, is required to block the water influx that generally involves high operational and material costs.
This extended abstract proposes a new cost-effective method of creating a low-permeable barrier against the produced water with induced formation damage. The method includes applying induced formation damage to block the water influx without hindering the oil production.
This can be achieved by injection of a small slug of fresh water into the water-producing layer. This results in release of in situ fines from the matrix, which can decrease permeability and create a local low-permeable barrier to the producing water.
In large-scale approximation, water injection with induced fines migration is analogous to polymer flooding. This analogy is used to model the fresh water with induced formation damage.
Sensitivity studies showed that the injection of 0.01 PVI of fresh water resulted in the blockage of the water-producing layer and an incremental recovery by 8% in field case A, with respect to the standard production scenario. The authors found that the incremental gas recovery with induced formation damage was sensitive to reservoir heterogeneity, permeability reduction and slug volume.
Crystal balls and current affairs: the financial challenge of a changing climate to the oil and gas industry
Authors: Davis Adam
Published: August 2017

Despite debate, the fact remains that the climate is changing. When considering the factors that determine potential financial impacts and losses that upstream oil and gas business could suffer due to a changing climate, the issues may primarily appear to be related to weather and geography. On closer examination, the factors that determine the severity of the impacts and losses are largely determined by the design and interdependencies of the financial and economic mechanisms of risk management. There is an increasing consensus in the insurance industry that the challenge presented by climate change, along with the increasing power of climate models, will result in far-reaching changes to the presently accepted practices of risk transfer. This extended abstract describes the increased power of climate models and the improved understanding of the present levels of under-adaptation when viewed from the position of investors in large-scale and long-lived oil and gas assets in Australia. It then looks at risk transfer models and examines potential limitations that have been identified due to the focus on ad-hoc post-disaster recovery when compared to a cost-effective pre-disaster resilience approach. The extended abstract then discusses how changes in the risk transfer approach could affect the financial aspects of an oil and gas business, such as the cost of borrowing, self-insurance, capital allocation and planning.
LNG demand: do we have enough gas? Our gas prices? Our gas future? Somebody help!
Authors: Adisa Olumide
Published: August 2017

These are interesting times for the eastern Australian gas market with Liquefied Natural Gas (LNG) projects coming online. The previously steady and long-term contract market for domestic gas supply on the east coast will be subject to market forces that are in part determined on the global stage. How will the market respond to these changes?
The answer requires a comprehensive analysis of several scenarios and sensitivities around market models, as well as sophisticated modelling to capture these possibilities. This requires a tool that allows detailed modelling of the physical delivery of gas from producing fields, through pipelines and storages (including linepack) to demand points, with the capability to model any physical/financial constraint along the supply chain. The future lies in these scenarios and sensitivities.
Employing a model developed through PLEXOS® gas module, this extended abstract analyses the effect of LNG on the domestic gas prices and supply in the short-to-medium and long-term. To establish any potential risk of gas shortage or particularly high prices, an analysis of the market was carried out from 2014-2023. Running several sensitivities on the demand forecast in this period, LNG effects on the market operations are examined.
Mesozoic rift onset and its impact on the sequence stratigraphic architecture of the Northern Carnarvon Basin
Authors: Gartrell Anthony , Torres Jose , Dixon Matt , Keep Myra
Published: August 2017

Ages varying from Late Triassic to Early Jurassic have been proposed by different authors for the onset of rifting in the Northern Carnarvon Basin. Seismic sections from the Exmouth Sub-basin and outer Exmouth Plateau demonstrate significant growth strata associated with displacement on normal faults starting at least at the base of the R. rhaetica zone (Rhaetian). This tectonic event coincides with a marked change in sequence architecture and a large landward shift (~300 km) of the paleo-shoreline to the vicinity of the Rankin and Alpha Arch trends. Rapid creation of accommodation in the inboard narrow rift basins (Exmouth, Barrow and Dampier sub-basins) is suggested to be the most likely cause of this major transgression. The preferential development of associated carbonate build-ups during the Rhaetian on the footwall side of active tilted fault blocks provides additional evidence for the onset of significant extensional faulting occurring during this time. An earlier more subtle initiation phase of rifting, however, is interpreted during the Norian, from around the middle part of the H. balmei biozone time, above which a change in stratigraphic architecture from aggrading to retrograding occurs. The observed structural and stratigraphic transitions can be related to typical phases of evolution described in many rift basins around the world. The work highlights the importance of integrating regional structural geology, sequence stratigraphy and depositional systems observations to provide robust constraints for basin evolutions.
The patchwork approach to the regulation of fraccing and unconventional gas in Australia
Authors: Hedge John
Published: August 2017

With hydraulic fracturing, shale gas, tight gas and coal seam gas continuing to be a target for environmental and landholder groups, and an issue politicians of all stripes continue to grapple with (in both cases, often without understanding the nuances of what those various terms mean), the legal framework under which they are regulated is changing rapidly.
From the moratoriums in Victoria and Tasmania through to the more open regimes operating in Queensland, SA, WA and the NT, the regulatory responses have varied wildly across Australia. This has resulted in investment outcomes being focused in those states and territories where the regulatory framework for unconventional gas is more welcoming. There are also regimes undergoing development as this paper was being written, as is presently occurring in the NT with the release of the Onshore Oil and Gas Guiding Principles, the pause and reset that is occurring in NSW with the implementation of the NSW Gas Plan, and the recent WA and anticipated SA responses to recent parliamentary inquiries.
This paper provides a comparative analysis of where the legal frameworks in the various states and territories presently stand on some of the key issues for unconventionals, and considers likely future developments in those legal frameworks. Regarding future developments, the paper covers both the short-term outlook based on announced inquiries, policies and processes, and whether there is hope in the medium to longer term—with some political will, the assistance of further scientific inquiries and a longer period of practical experience with unconventional gas operations Australia—of the convergence towards a more consistent regulatory approach across Australia.
Innovative borehole treatment utilising inflatable packer straddle system technology
Authors: Loginov Arthur , Aminkhaki Morteza
Published: August 2017

Open hole fracturing and acid stimulation utilising the traditional cemented liner and hydro jet perforations or mechanical packers with ball-activated frac sleeves have been deployed successfully in the US and Canada for years. One of the primary concerns about the conventional liner methods is assurance of knowing where the fracture or acid is placed. There is no way to determine if there is adequate annular isolation to ensure the planned treatments are placed in the zone of interest.
In cased holes, conventional methods to stimulate perforated zones through matrix and fracture acidising would require isolating and stimulating each zone separately in multiple trips. Otherwise, bull-heading treatments with large volumes of fluid would make it difficult to control the penetration rate into the fractures, and zones could not be selectively acidised. To eliminate these issues, an inflatable packer straddle system was run in eight tight CSG reservoirs in the Bowen Basin (Queensland). The system was run to stimulate these reservoirs in two vertical wells with cased hole perforations.
It is understood that this was the first use of this process in Australian CSG wells.
This paper addresses the main considerations of tool operation, case histories highlighting job procedures, and lessons learned from previous operations. It also addresses the use of other tools with the straddle system and possible modifications to the system to make it suitable for operational conditions where higher rates and abrasive sand-laden fluids are required.
Addressing the CSG–LNG economic challenge with surface engineering solutions
Authors: Hough Nigel
Published: August 2017

Since 2014, Australia’s LNG producers have seen a significant reduction in LNG price. To support ongoing profitability, the Australian CSG–LNG industry must reduce the cost of the additional surface infrastructure required to sustain gas production to their LNG processing plants. This paper explores how engineers can assist the Australian CSG–LNG industry to reduce the cost of that sustain phase surface infrastructure.
Through use of a case study, this paper concludes that the ability of the engineer to significantly reduce costs through detailed design optimisation and project execution are limited. To significantly lower costs, the engineer must be mandated to review and challenge the established upstream infrastructure design as part of a revisited concept select stage.
The revisited concept select stage should consider a philosophy that initially provides infrastructure with only the minimum functionality and capacity to ensure safe transfer of production fluids into the gathering networks. For any particular well, modular additions could be made to that infrastructure, if economically justified, based on the known performance of that well.
Through use of a minimal cost base design that is flexible and expandable, the engineer can allow for the unique performance of any particular well or field section without subjecting the project to the high cost of providing unnecessary infrastructure on each well.
To support the recommended approach, small and knowledgeable engineering teams who are willing to challenge the status quo and incorporate lessons from present operations will be required.
Maximising value by using good data to drive good decisions
Authors: Shields Aidan , Mirhan Marivic , Stratford Emma
Published: August 2017

The industry-wide move towards big data and the digital oilfield is underpinned by good data. This paper outlines a suite of data management standards, systems and processes, and provides examples of how these have led to improved decision making.
The approach involved the development of standards and streamlined business processes followed by the implementation of systems focusing on production data accessibility, quality and integration. Accessibility was addressed by making real-time data readily available from multiple devices so users spend more time using data instead of locating it. Quality was improved through the implementation of processes such as operational data validation (ODV) and production allocation (PA). Integration was facilitated so that users could view data from various systems in a single location.
The implementation of data management standards, systems and processes led to improved decision making in the areas of external reporting, operating cost, safety, environment, commercial, reservoir management, well surveillance, and situational awareness. In particular, implementation of the ODV process ensured the completeness, accuracy and timeliness of data from reservoir to sales. Furthermore, improved accessibility and integration increased situational awareness, reduced troubleshooting time, and improved problem analysis.
While the concept of data management and quality control is not new, the novelty is in the approach of developing robust standards, implementation of systems based on these standards, and creating the supporting business process and culture aligned to what drives value in the organisation. This is easily transferable and adaptable across all facets of the petroleum industry.