bluuebunny/crossref_metadata_2025 huggingface dataset:
Concurrent 5. Presentation for: Uncertainty analysis on environmental impacts of hydraulic fracturing
Authors: Movassagh Abbas
Published: June 2022

Presented on Tuesday 17 May: Session 5 Uncertainty is an undeniable aspect of underground operations, such as wellbore stimulation treatments, where combined rock and fluid interaction add a layer of complexity to the uncertainty. There are social and environmental concerns about the probable outcome of operations like hydraulic fracturing. Hydraulic fracturing treatments may affect the integrity of sub-surface geological strata or might initiate unexpected potential risks to the environment when the created fracture extends beyond its engineered design. Therefore, it is necessary to investigate a range of possible scenarios by which the fracture may experience a deviation from its planned behaviour. In this study, we model the uncertainty associated with hydraulic fracturing using fracture growth simulation. The uncertainty of a range of treatment parameters, such as pumping flow rate, injection duration and mechanical properties of the underground geological layer, is investigated. Monte Carlo simulation is used to examine different probable fracturing scenarios and numerous fracturing simulations with numerical and analytical models. The probability analysis is performed in a case study to identify the cumulative distribution functions (CDFs) of fracture growth. The emerging least, median and most likely situations of fracture growth are analysed to evaluate the fracturing uncertainty. Our results indicate that the numerical modelling approach may predict a more extensive fracture growth in the vertical plane. The numerical model may suggest a more conservative way to address environmental concerns. The resulting cumulative distribution of probabilities suggests the CDFs of the analytical model as the lower band for fracture length, whereas the numerical CDFs presents the upper band. To access the presentation click the link on the right. To read the full paper click here
Concurrent 6. Presentation for: Progressive sanding evaluation at different stages of the Geographe field development, Otway Basin
Authors: Younessi Ahmadreza
Published: June 2022

Presented on Tuesday 17 May: Session 6 Sanding risk assessments were conducted at different stages of development of Geographe field in the Otway Basin, Australia. The initial sanding analysis was conducted using the exploration and appraisal wells data in 2010. This analysis showed low sanding risk for the planned wells with the expected production plan. The sanding model was then updated in 2014. Logs, core tests and sand-free production data from the early production wells were used to improve the initial sanding model. The updated model reconfirmed the low sanding risk for planned horizontal wells and suggested no sand control would be required even at high depletions. The last model update was conducted in 2019 taking the advantage of about 5 years of sand-free gas production from two long horizontal laterals, with no downhole sand control. As of early 2022, the horizontal wells are still producing sand-free with depletion approaching more than 75%. A geosteered long horizontal well (approximately 2.1 km) at a different azimuth was drilled in the latter part of 2021. As the updated sanding model showed negligible risk of sanding for the planned well, a sand-face completion with pre-drilled liner was implemented. The progressing sanding analyses helped to augment the reliability of the initial prediction by calibrating against the actual production data from two horizontal wells. Drilling and production experiences are used to optimise geosteering and confirm suitability of the completion system for the well including later life of the field at high-pressure depletion condition. To access the presentation click the link on the right. To read the full paper click here
Concurrent 6. Presentation for: Effects of rapid gas decompression on coal seam gas swellables
Authors: Bon Jan
Published: June 2022

Presented on Tuesday 17 May: Session 6 Thousands of non-stimulated coal seam gas (CSG) wells in Queensland’s Surat Basin rely on swellable packers as the first line of defence against interburden solids production and poor well run life. This paper is aimed at understanding some of the impacts of long-term well operations on swellable performance from rapid changes in downhole pressure. For the first time, rapid gas decompression (RGD) effects on CSG swellables were experimented on in a quantitative manner as an analogue to underbalanced workover and pump trip conditions. RGD has the potential to break down swellables due to rapid release of high-pressure methane diffused in the rubber matrix resulting in a flow path for interburden solids. Five commonly available swellables from the CSG market were lab-tested for rapid decompression with methane at operational conditions. Coupon samples were swollen to representative conditions and placed in an autoclave under high-pressure methane, then rapidly decompressed in cycles. Results of this study showed relatively low levels of physical degradation under test conditions but shrinkage effects varied between products largely grouped into material properties, confirmed with separate ambient shrinkage test. As such, the focus on swellable placement geometry remains paramount. To access the presentation click the link on the right. To read the full paper click here
Concurrent 7. Presentation for: Coexistence 2.0 – maturing the coexistence model in Queensland
Authors: Thomas Jon
Published: June 2022

Presented on Tuesday 17 May: Session 7 For the gas industry to continue to thrive in a changing world, the evolution of coexistence will need to consider the multi-faceted aspects of community expectations such as the environmental, social and governance (ESG) factors, community expectations of a decarbonised energy future, technological advancements and changing government regulations. This paper does not define coexistence, rather it examines how the concept of coexistence in Queensland is a process of evolution as the gas industry in Queensland has matured from the perspective of the GasFields Commission Queensland (the Commission). The Commission was officially established in 2013 to ‘manage and improve the sustainable coexistence of landholders, regional communities and the onshore gas industry in Queensland’. There is no single means to obtain a good practice of coexistence. It requires a tailored approach dependant on the individual stakeholder, and will require the use of multiple tools, consistent engagement, transparent communication and a fit-for-purpose regulatory framework. Importantly, coexistence is a concept that requires a shared responsibility and is an enduring relationship. To access the presentation click the link on the right. To read the full paper click here
Concurrent 7. Presentation for: Biodiversity protection offsets in the Northern Territory – the Ichthys LNG story
Authors: Davis Ben W.
Published: June 2022

Presented on Tuesday 17 May: Session 7 Protection of land and sea country in the Northern Territory (NT) for biodiversity offsets is difficult. Land tenure, competing management priorities and a lack of data mean securing land for conventional offsets, especially for long-term projects, is problematic for potential offset scenarios. Despite these challenges, the INPEX-led Ichthys Joint Venture is required to protect an area of land and sea country in the NT to offset the perceived impacts to the environment of the Ichthys LNG energy development. The requirement stems from the Commonwealth Government Approval EPBC 2008/4208 Conditions 11(b) and 11(c); and relates to the development of Ichthys LNG at Bladin Point and associated dredging activities. Numerous attempts have been made by INPEX, on behalf of its Ichthys Joint Venture participants, to meet these offset requirements, spanning a 10-year history and involving multiple stakeholders. Many lessons have been learnt along this journey, and this paper aims to shed light on INPEX’s attempts to find practical solutions to these challenges. Recently, the Commonwealth Government accepted a novel industry approach put forward by INPEX to work with Aboriginal Traditional Owners to protect and manage country for future generations. If successful, it is expected to deliver positive outcomes beyond the environment it protects. To access the presentation click the link on the right. To read the full paper click here
Concurrent 9. Presentation for: Managing offshore Australia and its resources
Authors: Gaddes Shane
Published: June 2022

Presented on Wednesday 18 May: Session 9 The Australian Government manages over 10 million km2 of ocean, one of the largest marine jurisdictions in the world. Australia’s marine estate is a significant and growing source of wealth for all Australians. The area is used by a range of industries, government and persons for various purposes including shipping and navigation, tourism, conservation, culture and heritage, commercial and recreational fishing, oil and gas exploration and production, and defence activities. Looking ahead, activities such as carbon capture and storage (CCS) and offshore renewable energy will be active in the offshore. This paper explores the regulatory frameworks which govern interaction and co-existence of CCS projects, petroleum exploration and development and offshore wind proposals in Commonwealth waters. To access the presentation click the link on the right. To read the full paper click here
Concurrent 10. Presentation for: Unlocking Gippsland reserves with a minimum kit solution – West Barracouta
Authors: Kubik John
Published: June 2022

Presented on Wednesday 18 May: Session 10 The West Barracouta (BTW), field one of the largest proven undeveloped gas fields off the south-eastern Australian coast, commenced production in April 2021. The project was developed by Esso-BHP Gippsland Basin Joint Venture (JV), a 50–50 JV between ExxonMobil’s subsidiary Esso Australia and BHP Petroleum. The BTW gas field is situated ~6 km south west of the existing Barracouta gas field and platform, the first Gippsland Basin Joint Venture platform in Bass Strait. The BTW development involved drilling two subsea production wells, installation of umbilical controls from the existing platform and installation of a ~6 km subsea flowline to connect to existing gas pipeline via a hot tap. The BTW team will share insights on how it: (1) utilised minimum kit solution and verification of existing asset condition; subsea hot tap into operational gas pipeline and re-use of existing platform J-tube to minimise works on and around the Barracouta Platform (including diving work). (2) Managed an Operator first – co-mingled wet gas subsea pipelines while operating in hydrate regions; via detailed water detection metre/software solution, downhole zone isolation and systematic operating guidelines. (3) Leveraged Installation Contractor competitive Front End Engineering and Design (FEED) enabling optimisation of facilities design/execution strategies to align with strengths and maximise overall project value. (4) Leveraged the OneSubsea/Subsea 7 Subsea Integration Alliance and global worldwide network to execute the subsea design (including qualification), manufacture and installation. (5) Utilised the incumbent Engineering, Procurement and Construction (EPC) contractor to integrate the subsea and topsides control systems to support a single operation system linked to the existing to Distributed Control System (DCS). To access the presentation click the link on the right. To read the full paper click here
Concurrent 10. Presentation for: Honey, I shrunk the boat? Uncrewed subsea inspections leveraging remote operations technology
Authors: Zhao Yating
Published: June 2022

Presented on Wednesday 18 May: Session 10 Between May and November 2021, Woodside, in collaboration with Fugro, completed multiple, world-first, fully uncrewed inspection campaigns of trunklines and subsea infrastructure in the North West Shelf, all utilising a surface vessel and underwater robot (ROV), remotely operated via beyond-line-of-sight satellite communications architecture. Similar work is traditionally performed by a Multipurpose Support Vessel (MPSV) with >50 people onboard, consuming >20 m3/day fuel during transits. Transition to uncrewed remote operations technology has enabled the use of a much smaller (12 m) vessel, removing health and safety risk associated with offshore crew, and with <0.2 m3/day fuel consumption during transit. High-resolution hull and ROV-mounted multi-beam data, ROV-mounted laser point cloud data, ultra-high-definition images and videos and Cathodic Protection (CP) field gradient data were all successfully collected, and operations were completed from the busy Dampier Port with no incidents. Delivery of this landmark achievement was enabled by a multi-year staged technology plan in collaboration with Woodside’s subsea Inspection, Maintenance and Repair (IMR) contractor, Fugro, including establishment of a dedicated remote operations centre based at International Communications Facility. Extensive stakeholder engagement was performed internally and with external regulatory bodies to ensure that all risks were captured, understood and managed so that all parties were aligned on implementation of the novel approach. Application of this technology is forecast to transform the costs of IMR operations vs traditional methods, effectively eliminate carbon emissions and offshore personnel exposure hours, and create opportunities for a more diverse workforce in the sector. To access the presentation click the link on the right. To read the full paper click here
Concurrent 11. Presentation for: The future energy leader: a millennial dilemma
Authors: Mahapatra Polly
Published: June 2022

Presented on Wednesday 18 May: Session 11 Undoubtedly, there is an industry-wide urgent need to build a strong talent pipeline for the future, especially in the face of climate change. The future energy leader must be multi-faceted and exceptionally skilled, with the further challenge to be able to humanise the industry. They must balance the need for energy affordability and security alongside climate neutrality and articulate this complex industry to those outside of it. While there is a general industry consensus that finding appropriate talent to plug these gaps is becoming increasingly difficult, little work has been done in the space of practical, implementable solutions to solve this issue. With current data suggesting an aging workforce and high percentage of industry retirements at our doorstep, the time is appropriate for research into the problem at hand. This paper methodically outlines the current dilemma being faced in the recruitment and retention of young professionals, with particular emphasis on the data trends and higher education statistics as relevant to the local demographic of Perth, Western Australia. The paper will also suggest what future skills should be prioritised in order to progress industry goals. This paper outlines the strategies that Chevron Australia has leveraged in order to tackle this issue including, but not limited to, industry engagement, university engagement, human capital trends and predictive analytics. This paper includes example case studies from within Chevron Australia used to tackle this issue with an aim to apply the strategies on an industry-wide scale to come to a collective resolution. To access the presentation click the link on the right. To read the full paper click here
Concurrent 12. Presentation for: Recycling of Australian oil and gas assets, an Australian Basel-compliant solution
Authors: Soliman Hunter T.
Published: June 2022

Presented on Wednesday 18 May: Session 12 Australian offshore petroleum infrastructure decommissioning strategies are dictated by legal requirements set out in the Offshore Petroleum and Greenhouse Gas Storage Act, requiring prima facie that assets are removed from the title area. Legally, once assets are decommissioned, they require disposal at a Basel-compliant facility. This lack of Australian capability has forced titleholders to contemplate leaving infrastructure in situ (rigs-to-reef), which may well breach Australia’s international law obligations under the United Nations Convention on the Law of the Sea, and the London Convention on Dumping at Sea (and associated Protocols). Australia’s closest Basel-compliant facility is located in Turkey. The experience of the Iron Chieftain in 2019 demonstrated the difficulty in using this facility. In 2019 the bulk carrier Iron Chieftain caught fire in Port Kembla, and was declared a Constructive Total Loss (CTL). Disposal required decontamination, seeking Basel export approval, and towing to Turkey via South Africa. Following 9 months to complete the application, the vessel commenced its tow. The vessel was not permitted to stop or enter the port waters of any port other than Turkey after leaving. If it did stop, the application ceased and a new application was required to be commenced. If the vessel arrived in a condition not acceptable to authorities, the vessel would be turned away, requiring it to return to its home port of Port Kembla where the application commenced from. In response to such difficulties, a new Basel-compliant recycling facility has been established, co-located to a green steel recycling works, delivering a near carbon-neutral asset recycling and disposal solution for Australia’s offshore energy infrastructure. Strategically located in the mouth of the Spencer Gulf, South Australia, this facility will provide a green whole-of-asset recycling and disposal solution in-country, removing towage expenses and CO2 emissions. This extended abstract articulates the Iron Chieftain experience, highlighting the issues facing petroleum infrastructure decommissioning and disposal in accordance with Basel requirements. It also provides an overview of the Whyalla recycling and disposal facility, presenting the case for circular economy, ethical asset decommissioning and Australian capability. To access the presentation click the link on the right. To read the full paper click here
Concurrent 13. Presentation for: 2021 Development and production review
Authors: Wilkes Martin
Published: June 2022

Presented on Wednesday 18 May: Session 13 The Petroleum Exploration Society of Australia (PESA) Year in Review Development and Production review looks back at the oil and gas production and development activities in Australia in 2021, with a look at both the historical context of these activities, and the future implications. With the impact of COVID-19 continuing throughout the year, and increased awareness of the impact of emissions on climate change there were several notable highlights and events for the year. Liquefied natural gas (LNG) production hit record high levels and confirmed Australia as the current top LNG exporting country in the world. Two major LNG-related projects were sanctioned: Barossa in March 2021, and Scarborough/Pluto 2 in November 2021 and the Moomba Carbon Capture and Storage project was also sanctioned in November. The domestic market looked a lot like the classic novel ‘A Tale of Two Cities’ with major concerns about gas supply in the East contrasting with significant discoveries and development in the Perth Basin in the West. To access the presentation click the link on the right. To read the full paper click here
Concurrent 14. Presentation for: New imaging results and improved interpretation of Late Triassic depositional features within the Browse Basin, North West Shelf of Australia
Authors: Grahame Jarrad Paul
Published: June 2022

Presented on Wednesday 18 May: Session 14 The Maxima 3D is located approximately 300 km from the north-west coast of Australia, within the Brecknock–Scott Reef anticlinal trend, at the margin of the Scott Plateau and Caswell Sub-basin. The survey was acquired with eight overlapping swaths in and around the Scott Reef, which is a large carbonate build-up on the present-day seafloor. The area within and around the reef trend represents a significant challenge for imaging, involving complex survey acquisition, very shallow to deep water depths and strong velocity distortion associated with the present-day carbonate build-up. In light of this, CGG undertook a reprocessing test of a swath of the Maxima 3D, to apply the latest processing techniques and demonstrate the potential imaging uplift in a very challenging area. The enhanced data swath has led to a step change in interpretation capabilities for the data, resulting in the identification of what is inferred to be a Late Triassic, isolated reef build-up, on a structural high that developed contemporaneous with early basin formation. These Late Triassic reefal build-ups have been identified by CGG within a number of large complexes, through a comprehensive review of the Triassic prospectivity potential, and represent an emerging play type for the North West Shelf. To access the presentation click the link on the right. To read the full paper click here
Concurrent 15. Presentation for: Trusted environmental and geological information to support Australian energy resource development in a changing world
Authors: McAlpine Sarlae R. B.
Published: June 2022

Presented on Wednesday 18 May: Session 15 The Australian Government’s Trusted Environmental and Geological Information (TEGI) program is a scientific program led by Geoscience Australia. The program is part of the Government’s Strategic Basin Initiative under its Gas-fired Recovery agenda, implemented as a post-COVID19 response to stimulate the economy. This program will deliver regional geological and environmental assessments underpinned by transparent, trusted baseline geological and environmental data, commencing in the north Bowen and Galilee and the Cooper and Adavale Basins. This repository of information is to be used in support of bringing forward energy and mineral developments in basins identified by the Government as strategic. This paper discusses how coupling resource assessments with baseline information such as groundwater, geology, energy and mineral resources, surface water and protected environmental matters, can be used to support exploration and development decisions by industry, regulators and other stakeholders. For example, by establishing a regional baseline resource assessment, through prospectivity play mapping, environmental assessments can be prioritised to match resource prospectivity. In anticipating future development scenarios, potential impacts on environmental assets, including groundwater, can be assessed in advance and with key knowledge gaps identified for redress. This approach aims to optimise the regulatory pathway to resource development and increase regulatory efficiency as future development opportunities arise across the scope of petroleum, minerals, carbon capture and storage, and hydrogen storage and production. An example of Geoscience Australia’s work on the Adavale Basin is presented in this paper describing the first steps in linking energy resources and environmental assessments in a changing world. To access the presentation click the link on the right. To read the full paper click here
Concurrent 17. Presentation for: Resource potential of the Carrara Sub-basin from the deep stratigraphic well NDI Carrara 1
Authors: Bailey A. H. E.
Published: June 2022

Presented on Wednesday 18 May: Session 17 NDI Carrara 1 is a deep stratigraphic well completed in 2020 as part of the MinEx CRC National Drilling Initiative (NDI), in collaboration with Geoscience Australia and the Northern Territory Geological Survey. It is the first stratigraphic test of the Carrara Sub-basin, a newly discovered depocentre in the South Nicholson Region. The well intersected Proterozoic sediments with numerous hydrocarbon shows, likely to be of particular interest due to affinities with the known Proterozoic plays of the Beetaloo Sub-basin and the Lawn Hill Platform, including two organic-rich black shales and a thick sequence of interbedded black shales and silty-sandstones. Alongside an extensive suite of wireline logs, continuous core was recovered from 283.9 m to total depth at 1750.8 m, providing high-quality data to support comprehensive analysis. Presently, this includes geochronology, geochemistry, geomechanics and petrophysics. Rock-Eval pyrolysis data demonstrate the potential for several thick black shales to be a source of hydrocarbons for conventional and unconventional plays. Integration of these data with geomechanical properties highlights potential brittle zones within the fine-grained intervals where hydraulic stimulation is likely to enhance permeability, identifying prospective Carrara Sub-basin shale gas intervals. Detailed wireline log analysis further supports a high potential for unconventional shale resources. Interpretation of the L210 and L212 seismic surveys suggests that the intersected sequences are laterally extensive and continuous throughout the Carrara Sub-basin, potentially forming a significant new hydrocarbon province and continuing the Proterozoic shale play fairway across the Northern Territory and northwest Queensland. To access the presentation click the link on the right. To read the full paper click here
Concurrent 18. Presentation for: Minimising pipeline leaks and maximising operational life by application of machine learning at Cooper Basin
Authors: Khalilpasha Hossein
Published: June 2022

Presented on Wednesday 18 May: Session 18 The development of technologies in the last few decades has enabled operators to collect significantly more data than previously possible. Despite availability, making data-driven decisions on asset health, and developing efficient asset management strategies, is not common. This is mainly due to challenges with compilation, and alignment of all the data into a comprehensive picture of pipeline integrity, as it consumes significant resources deploying conventional methods. A critical advantage of modern data storage, analysis and visualisation techniques is the relative ease of performing statistical assessments of integrity data. Analysis of correlated data can be equally challenging as algorithms used can be overly simplistic and inaccurate. Machine learning algorithms parse, analyse and learn from data, enabling the operators to make an educated decision. This has been extensively deployed in other industries such as finance, healthcare and supply chain management but has never been fully developed and enhanced in pipeline integrity industry until very recently. This paper provides an overview of the development in machine learning tools in pipeline integrity, allowing enhancement of asset performance, through the application of machine learning and automation, to predict integrity threats, and prevent leaks and failures. It provides a case study where a tool was developed, and this technique was successfully implemented across a significant number of upstream pipelines in the Cooper Basin, enabling the Santos integrity engineering team to make the most effective decisions on asset condition and to develop a data-driven asset management plan. To access the presentation click the link on the right. To read the full paper click here
Concurrent 19. Presentation for: Viral mutations, vaccine effectiveness and rapid tests – COVID-19 risk management in the two largest LNG producing countries, Qatar and Australia
Authors: Jeremijenko Andrew
Published: June 2022

Presented on Wednesday 18 May: Session 19 The SARS-CoV-2 pandemic created challenges for the oil and gas industry. Qatar experienced three significant waves during the pandemic that disproportionately affected the workers in shared accommodation. In Australia, the public health measures limited the spread of SARS-CoV-2 in the industry until the Omicron wave. Anti-SARS-CoV-2 seropositivity was assessed in five oil and gas subcontractors and five hospital subcontractors in Qatar between 21 June and 9 September 2020. Vaccine effectiveness was assessed in Qatar. Vaccine effectiveness in an LNG tanker crew off Gladstone was calculated. The initial study in Qatar included 4970 craft manual workers (CMWs) who were mostly men (95.0%). Infection positivity (antibody and/or polymerase chain reaction (PCR) positive) ranged from 62.5% (95% CI: 58.3–66.7%) to 83.8% (95% CI: 79.1–87.7%). Only five infections were severe and one was critical – an infection severity rate of 0.2% (95% CI: 0.1–0.4%). Rapid antibody tests (RATs) were effective in diagnosis of the SARS-CoV-2 virus infections. Vaccine effectiveness against severe, critical or fatal infections were above 90% in both the Qatar and Australian studies, but protection against infection waned significantly after 6 months. In Qatar and Australia, the industry implemented effective control measures including the use of RATs, PCR tests, test, trace, isolation, quarantine (TTIQ) and vaccination. In both countries, the LNG industry collaborated with public health experts and other experts and was involved in research to assess and manage the risk of COVID-19. Production of LNG was not affected. Participation in public health research in both countries contributed to important scientific publications and protected the industry. COVID-19 may become endemic. To access the presentation click the link on the right. To read the full paper click here
Concurrent 19. Presentation for: Mental health and the resources sector: findings from a research program to promote effective mental health solutions
Authors: Kelly Brian
Published: June 2022

Presented on Wednesday 18 May: Session 19 This paper outlines a multifaceted national workplace mental health research program that incorporated assessment of individual level, work characteristics and organisational factors on mental health among workers in the resources sector within Australia and internationally. This multistep program included: identification of level of mental health and substance use problems in an Australian national study; examination of risk and protective factors (work roles, social networks and location); attitudes to seeking mental health assistance; organisational policies regarding mental health within a workplace health and safety framework; piloting a resources-specific workplace mental health program for team leaders and supervisors and a workplace suicide prevention program; and application of digital mental health interventions to this sector. Additional linked studies in New South Wales and Queensland in the resources sector assessed personal factors influencing perception of workplace physical risks and hazards, risk behaviours and opportunities for risk mitigation; and links between mental and physical health factors. A summary of the key findings are presented within the context of a program of research addressing mental health within remote settings in the resources sector. Mental health-related problems are highly prevalent among workers in remote resource settings, which has significant implications for workplace health and safety. Strategies to address prevention and effective intervention need to be tailored to the industry and employee characteristics, and address models of mental health care that are feasible and accessible in often remote and challenging environments. To access the presentation click the link on the right. To read the full paper click here
Concurrent 20. Presentation for: The business of growing a hydrogen business: lessons from disruptive innovation theory
Authors: Wheeldon Megan
Published: June 2022

Presented on Wednesday 18 May: Session 20 To date, the oil and gas transition to hydrogen production has largely been focused on the techno-economic feasibility of hydrogen hubs. While techno-economics are essential for business case development, so too is the requirement to adjust business models and organisational culture to support new market entry. To analyse this perspective, this paper has reviewed Christensen’s theory of disruptive innovation and its application to hydrogen business growth in incumbent oil and gas companies. In doing so, the author presents the conclusion that disruptive innovation in a hydrogen context will not be the technology itself, but rather in how organisations innovate their business models to meet shifting market priorities. To access the presentation click the link on the right. To read the full paper click here
Concurrent 21. Presentation for: Ground surface monitoring for CO
Authors: Movassagh Abbas
Published: June 2022

Presented on Thursday 19 May: Session 21 Tracking the migration of injected CO2 is critical to understanding the performance of subsurface intervals selected for CO2 sequestration. Subsurface CO2 injection may cause a deformation at the surface of the earth. Measuring and analysing the shape and magnitude of this surface deformation provides confidence that sequestered CO2 will remain in the target formations and can alert operators to the existence of hidden faults or fractures which may necessitate redesign of the injection schedule or remediation of the geological hazards. Surface deformation information for onshore injection operations can be obtained via Interferometric Synthetic Aperture Radar (InSAR) satellite imagery or an array of high-precision tiltmeters installed in 10–15 m deep boreholes. However, in the case of offshore injection operations, InSAR data is not available. Due to the lack of tilt data at In Salah field at Krechba, Algeria, synthetic tilt data has been produced using a 3D forward model. The synthetic tilt time-series data at ten locations around each injection well has been used in inverse analysis. Results show that the shape and direction of the CO2 plume in the subsurface can be accurately determined through inverse analysis of the tilt time-series data. To access the presentation click the link on the right. To read the full paper click here
Concurrent 21. Presentation for: Gold (hydrogen) rush: risks and uncertainties in exploring for naturally occurring hydrogen
Authors: Stalker Linda
Published: June 2022

Presented on Thursday 19 May: Session 21 Interest in hydrogen (H2) energy has exploded in the last few years. Much of the interest comes from transitioning to a decarbonised energy future, through the use of renewables, to convert hydrogen-rich materials (methane, water) to pure hydrogen gas streams. Each of these methods have their own challenges, such as the need for carbon capture and storage to manage carbon emissions or perspectives on the use of fresh water. At the same time as this engineered approach to generating hydrogen, there has been a quiet but exponential upsurge in research surrounding the origins and fate of naturally occurring hydrogen. Sometimes referred to as ‘gold’ or ‘white’ hydrogen, geological forms of hydrogen have been recognised for thousands of years. While already present as H2, hydrogen may exist with other gases, such as methane, helium, hydrogen sulfide and/or nitrogen. But is it real? Is it volumetrically significant, discoverable, predictable or exploitable? Early work suggests that we can begin to characterise potential sources of hydrogen, the depth ranges they may be generated from, the migration mechanisms that are relevant, and how they might be retained or lost in relation to the discovery and exploitation of this gas. However, existing publicly available data is constrained by a lack of analysis and limited evidence. While there are increased reports of seeps containing hydrogen, there is an absence of evidence of more significant finds and a lack of major analogues and case studies to date. We explore these risks and uncertainties and provide a roadmap for reducing the evidence gap. To access the presentation click the link on the right. To read the full paper click here
Concurrent 23. Presentation for: On a mission to decommission?
Authors: Aston Andy
Published: June 2022

Presented on Thursday 19 May: Session 23 E&P operators with ageing assets are making informed investment decisions around financial commitments for later-life asset management through to full decommissioning and abandonment in a safe, environmentally sound and cost-effective way. Factors affecting decommissioning decisions include: Oil price, New technology, Regulatory requirements, Supply chain and contracting options. Operators are optimising the execution of decommissioning projects and consistently looking to improve efficiencies through decommissioning strategies, technologies and approaches. At the same time, a new focus on programmatic approaches, and the use of data are becoming more prevalent to eliminate waste and create cost saving opportunities. This paper provides: an overview on the decisions that need to be taken when commencing decommissioning activities; a review of the various models and strategies for decommissioning and abandonment; discussion on how traditional project approaches may not be appropriate in light of environmental and sustainability targets; and consideration of contracting options. The paper will appeal to E&P operators, major contractors and service providers. To access the presentation click the link on the right. To read the full paper click here
Concurrent 23. Presentation for: Industry-wide learnings from the independent review of Australia’s most complex decommissioning program
Authors: Gray Alasdair , Wilson Chris
Published: June 2022

Presented on Thursday 19 May: Session 23 In 2019, the Minister for Resources and Northern Australia issued a Statement of Expectations to the National Offshore Petroleum and Safety Environmental Management Authority (NOPSEMA) establishing heightened expectations for duty holder compliance with their decommissioning obligations. In response, NOPSEMA increased compliance monitoring and enforcement activities to assess adequacy of the level of decommissioning planning and implementation by duty holders. On 20 May 2021, NOPSEMA issued a general direction to Esso Australia relating to their Bass Strait decommissioning program, likely one of Australia’s most significant and complex decommissioning projects. The direction included a requirement to undertake an independent review of Esso’s engineering and project management approach and consider if there were opportunities for reducing the timeframe to commence and subsequently complete all necessary decommissioning activities. This review was subsequently awarded to Xodus, in partnership with Labrador and focussed on core disciplines such as project management, regulatory approvals, stakeholder engagement, well plugging and abandonment, contracting, topsides and subsea facilities and waste management. Australia is at a pivotal stage in the context of decommissioning oil and gas infrastructure. With heightened regulatory oversight alongside recent and continuing changes to legislation, ensuring supply chain is ready to deliver against this backdrop will be critical to the future success of regional decommissioning and ensure all parties bearing the cost of this work are satisfied. This paper will discuss the independent review process of Esso’s decommissioning program and outline key challenges and opportunities the industry faces in realising improved decommissioning efficiency in the region. To access the presentation click the link on the right. To read the full paper click here
Concurrent 23. Presentation for: National Decommissioning Research Initiative outcomes inform offshore decommissioning options
Authors: Jarvis Samantha
Published: June 2022

Presented on Thursday 19 May: Session 23 The Australian offshore oil and gas industry is facing a significant decommissioning portfolio over the next few decades. In response to this, in 2019, eight Australian oil and gas operators and the National Energy Resources Australia (NERA) established the National Decommissioning Research Initiative (NDRI) with the aim to fill key knowledge gaps on the potential environmental impacts, risks and benefits of different decommissioning options in Australia’s offshore environment. In Phase 1, seven research projects were undertaken covering the interaction that occurs between the environment and oil and gas infrastructure in Australia’s oceans. These projects focused on habitat, connectivity, invasive marine species, degradation of metals and non-metals and potential contaminants of concern such as mercury and naturally occurring radioactive materials. Two other projects were undertaken to gain insights into regulators, stakeholders, marine users and scientist views on offshore decommissioning risks and opportunities. This paper describes the drivers for NDRI, the outcomes of the Phase 1 projects and the future projects to be undertaken to support the environmental assessment of different decommissioning options. To access the presentation click the link on the right. To read the full paper click here
Concurrent 23. Presentation for: Safety zones and decommissioning
Authors: Nelson Nicholas A.
Published: June 2022

Presented on Thursday 19 May: Session 23 Australia’s oil and gas sector expects approximately 56 billion (AUD) to be expended for decommissioning costs over the next 50 years. The view of the National Offshore Petroleum Safety and Environmental Management Authority is that the designated decommissioning approach must provide equal or better environmental outcomes when compared to full removal of the infrastructure (considered the ‘best case’ expectation under current legislation) and meets as low as reasonably practicable (ALARP) levels of risk. Decommissioning alternatives are generally evaluated through a comparative multicriteria assessment approach, for example, a net environmental benefit analysis-based comparative assessment (NEBA-CA). Decommissioning options cover a range of possibilities, from full removal to leaving subsea structure in situ (in part or in whole). NEBA-CAs we have conducted suggest that some subsea structures are projected to generate significant ecological and social value over multiple generations to come. Thus, in these cases, management in situ can provide greater benefits to the public when compared to full removal. During operation, oil and gas assets typically incorporate a safety zone. If subsea structure is selected to be managed in situ, a question that arises is, should the safety zone be maintained or removed? Our experience indicates that if the safety zone is removed after decommissioning an asset that is left in situ, there may likely be a greater adverse impact on ecological and social values, depending upon the asset location. This abstract showcases the value of the use of safety zones to maximise environmental value while managing risk. To access the presentation click the link on the right. To read the full paper click here
Concurrent 23. Presentation for: Building collaborative capacity to address Australia’s growing decommissioning needs
Authors: Norman Francis G.
Published: June 2022

Presented on Thursday 19 May: Session 23 Australia and indeed the Asia-Pacific region is facing a significant decommissioning workload. Recent work by the Centre of Decommissioning Australia (CODA) puts Australia’s potential offshore decommissioning cost at around US$40 billion and Wood Mackenzie predicting the region’s decommissioning to be in excess of US$100 billion. CODA was established in 2021 to support the coordinated effort required across the entire Australian value chain to address this immense domestic workload safely and effectively. Building on the release of the 2021 liability report, CODA, in conjunction with a number of operators, has undertaken three additional studies, looking at: planning and execution global best practice applicable to Australian operations; a decommissioning technology roadmap, and; a recycling and disposal pathways report. Supported by these studies to understand the current state and needs of the Australian decommissioning industry, CODA’s primary focus is to build domestic capacity and capability. To this end CODA is working with operators, the service and supply sector, state and federal government, regulators and researchers to establish a collaborative network that can enhance the visibility of upcoming work, surface and support the growth of domestic capability and share best practice in decommissioning. This paper highlights findings from the new reports and shares insights into CODA’s ongoing work to build an inclusive Australian decommissioning community of practice ready to undertake the next decades of activity. To access the presentation click the link on the right. To read the full paper click here
Concurrent 24. Presentation for: Supporting energy transition as a service contractor
Authors: Francis David
Published: June 2022

Presented on Thursday 19 May: Session 24 Service contractors are heavily engaged in the energy transition and decarbonisation process, designing and executing capital projects and asset upgrades that will sustain the new look economy. The next question is what can service contractors do to directly contribute to a reduction in carbon emissions and fossil fuel use? This review will examine the impact of updating our service delivery to drive down energy consumption and emissions, and plan for a future where renewable energy can power the field services we provide. Upstream Production Solutions (Upstream PS) has started on our journey of monitoring the greenhouse gas emissions for our business as per AS ISO 14064, and while we are below the 50 kt threshold for a registered reporting entity as per the Australian National Greenhouse and Energy Reporting Act 2007, the increased awareness has helped us identify key areas where we can make positive changes in our business and directly contribute to emissions reduction: development of fit for purpose company standards; optimised selection of mobile fleet; improved planning and scheduling leading to reduced kilometres driven and emissions; and incorporating low-emissions technology options into our services. Upstream PS will share our progress as we pursue practical improvements while maintaining, and even improving, the delivery of our services. To access the presentation click the link on the right. To read the full paper click here
Concurrent 24. Presentation for: Repurposing Victoria’s gas infrastructure for a net zero future
Authors: Khalilpasha Hossein
Published: June 2022

Presented on Thursday 19 May: Session 24 As the world moves towards a net-zero future, different jurisdictions are considering various scenarios on how they can achieve their targets. Depending on the types of assets within each jurisdiction, it could mean the development of new projects, modifying existing infrastructure, or a combination of both. The Victorian Climate Change Act 2017 established a system of coordinated, whole-of-economy actions to achieve a net zero emissions target by 2050. This includes rolling 5-year plans and targets to reduce emissions and adapt to climate change impacts, obliging all government policies, plans and decisions to consider climate change, and requiring all sectors of the economy including the gas industry to develop and action emissions reduction pledges. Natural gas plays a major role in Victoria’s energy mix with extensive gas infrastructure supplying over 2 million customers in Victoria and a network asset value of approximately A$6 billion. In 2021, Infrastructure Victoria provided its advice to the Victorian Government on potential scenarios for repurposing Victoria’s gas transmission and distribution networks in a future where Victoria’s carbon emission reduction targets are achieved. This paper provides the results of assessment on the suitability of existing gas infrastructure across the value chain to be repurposed for hydrogen blending, 100% hydrogen, biomethane and carbon dioxide service. This work was performed for the purpose of informing the Victorian Government of the opportunities and risks to gas infrastructure associated with achieving its 2050 net zero emission target. To access the presentation click the link on the right. To read the full paper click here