bluuebunny/crossref_metadata_2025 huggingface dataset:
Field-programmable ring array employing AMZI-assisted-MRR structure for photonic signal processor
Authors: Sun Yaohui , Wang Dongyu , Wang Lihan , Zhou Yue , Pan Shilong , Hu Guohua , Yun Binfeng , Cui Yiping
Published: June 2024

A field-programmable photonic gate array is an integrated optical chip that combines electrical control and optical processing, enabling real-time reconfiguration of the optical path through software programming. While most current optical processors rely on Mach–Zehnder interferometer (MZI)-based architectures, those based on micro-disk resonators (MDRs) offer unique characteristics, including high integration and wavelength correlation, providing new ideas for programmable photonic chip architectures. In this paper, a scalable asymmetric MZI-assisted field-programmable micro-ring array (AMZI-FPRA) processor is proposed with a cell area of only 85 × 42 µm2. This design not only has high wavelength selectivity but also possesses dual adjustable wavelengths and coupling coefficients compared with traditional MDRs. By extending the cell into a 2 × 2 AMZI-FPRA using a two-dimensional square mesh approach, it is experimentally demonstrated that different optical path topologies can be realized with a compact footprint, including bandpass bandstop filtering, optical temporal differentiation, microwave delay, wavelength-division multiplexing/demultiplexing, and optical add-drop multiplexing. Increasing the array scale will enable more versatile and high-performance microwave photonic signal processing tasks. The scheme will be a promising candidate at the present time for reconfigurable programmable photonic signal processors due to its wide reconfigurability, on-chip integration, complementary metal–oxide–semiconductor-compatibility, and low power consumption.
Session 2. Oral Presentation for: Comparative analysis of hydrogen production pathways for emethanol synthesis to decarbonise industry
Authors: Campbell Andrew P.
Published: June 2024

Presented on Tuesday 21 May: Session 2 Methane pyrolysis and water electrolysis offer alternative hydrogen pathways to methane reforming that utilise renewable power and avoid generating carbon dioxide (CO2). On a scope 1 and 2 basis, both technologies have the potential to generate carbon neutral emethanol fuel when combined with biogenic CO2. However, pyrolysis requires significantly less energy and has a lower capital expenditure (CAPEX). Being a more nascent technology, it also has upside potential for cost reductions and valorisation of the solid carbon by-product can yield lower hydrogen costs than the incumbent technology, however, limited demand from existing markets is a potential constraint. Industry decarbonisation is constrained due to a lack of available renewables and hydrogen infrastructure. Pyrolysis offers a potential cost-effective use of the available renewable assets in the early stages while the carbon by-product is not a constraint and until sufficient renewable infrastructure is in place to support water electrolysis at a cost-effective scale. To access the Oral Presentation click the link on the right. To read the full paper click here
Session 2. Oral Presentation for: Securing the Australian CCS project rollout by improving aspects of the GHG storage legislation: a discussion paper
Authors: O’Brien Geoffrey
Published: June 2024

Presented on Tuesday 21 May: Session 2 The respective Federal petroleum and greenhouse-gas (GHG) storage legislation was examined in detail to understand the interactions between the technical requirements in the legislation, the overarching emissions-policy framework and the existing and likely future technical capabilities of the carbon capture and storage (CCS) industry. Key elements of the GHG legislation were then stress-tested using CCS project examples to determine applicability. The number of CCS projects required to meet the nation’s emission reduction targets over the next 5–25 years is high (probably between 20–40 projects of 4 million tonnes per annum (Mtpa)), but the existing 8–10 year approvals timeline provides only a maximum of 2.5 full project cycles to undertake 20–40 projects, a goal not considered possible without substantial regulatory reform. Opportunities for improvement should focus on facilitating a robust and rapid CCS project rollout and could include the following: changing the legislation to facilitate the accelerated utilisation of depleted petroleum fields to storage facilities, including allowing the progressive expansion of the awarded injection licence (IL); changing the concept of containment to emphasise carbon dioxide (CO2) plume management via assessing risk and potential impacts, not by artificial constraints into GHG permits and licences; including unitisation and combination pathways in the GHG legislation; ‘CO2 plume’ is not defined in legislation, even though the spatial location of a plume is central to numerous approvals, such as declaration of storage, demonstrating containment and all measurement, monitoring and verification (MMV) programs; developing a framework to manage future CCS project interactions at a basin scale, as is undertaken in groundwater management onshore. To access the Oral Presentation click the link on the right. To read the full paper click here
Session 3. Oral Presentation for: Analysis of an existing hydrocarbon gas pipeline for conversion to dense phase CO2 service
Authors: Levy David
Published: June 2024

Presented on Tuesday 21 May: Session 3 Esso Australia is investigating the feasibility of a carbon capture and storage (CCS) project in East Gippsland, Victoria. Known as the South-East Australia Carbon Capture and Storage (SEA CCS) Hub, the project aims to re-purpose existing infrastructure and offshore depleted hydrocarbon reservoirs to store carbon dioxide (CO2). The project aims to reduce greenhouse gas emissions from Esso’s Longford Gas Conditioning Plant, and to unlock future CCS opportunities for Australia. One option identified as part of the SEA CCS feasibility was to convert part of the existing onshore section of the Barracouta 450 mm gas pipeline to Longford Gas Plant (BTA450-LFD), Licence PL/1 under the Victorian Pipeline Act, to dense phase CO2 service. This paper documents the initial findings of the potential for the onshore section of the BTA450 for conversion, with particular emphasis on brittle and ductile fracture control considerations. In summary, when attempting to convert existing hydrocarbon gas pipelines for CO2 service, operators need to undertake an appropriate assessment of fracture control considerations. The insights of this paper may serve as a useful guide document for assessing other existing onshore pipelines for CO2 service conversion. Due to the thermal modulation effect of the surrounding water for subsea pipelines, this guidance does not apply to subsea pipeline sections. To access the Oral Presentation click the link on the right. To read the full paper click here
Session 3. Oral Presentation for: EOR simulation of polymer flooding
Authors: Cueille Pierre-Victor
Published: June 2024

Presented on Tuesday 21 May: Session 3 Enhanced oil recovery (EOR) techniques, such as polymer flooding, have gained significant attention as a means to maximise hydrocarbon extraction from reservoirs. The success of polymer flooding is intricately tied to the complex interplay between fluid properties, reservoir heterogeneity, and injection strategies. It is admitted in classical modelling methodologies, to account for the mobility ratio in polymer flooding by scaling it with the help of the shear rate in situ. The accuracy of shear assessment therefore rules the mobility of oil and the global process efficiency. It is assumed to depend not solely on pore radius, rate, and porosity, but also on a dimensional parameter known as the shape factor, which varies according to the specifications of several authors. When lab measurement is available, it is possible to adjust this value to match the shear rate recorded from a rheometer at feeding stage, ahead of the core. In the present paper the consequence of not performing this stage in the case of a core flood, then in the simulation of a polymer flood pilot is investigated. An alteration of the recovery factor is then expected. The amplitude shall result from the coupling between pore-scale effects and reservoir-scale response, induced by geological constraints such as reservoir layers productivity, aquifer response, and multiphase dynamics. Relative effect and influence on reservoir parameters will be quantified, commented, and discussed. To access the Oral Presentation click the link on the right. To read the full paper click here
Session 6. Oral Presentation for: Don’t forget your keys when trying to unlock the productivity of low-permeability coals
Authors: Johnson Raymond L.
Published: June 2024

Presented on Tuesday 21 May: Session 6 Low-permeability coal seam gas (CSG) wells have been the subject of laboratory research and modelling studies over the past decade, particularly focusing on the pressure-dependent permeability (PDP) behaviour of coals. These research efforts have progressed diagnostic methods to identify and quantify PDP and provide practical technologies to counter these effects. Firstly, machine learning methods based on drilling and historical well-test data can provide insight into the range of coal permeability during drilling. Next, the process of history-matching the after-closure pressures from a diagnostic fracture injection test (DFIT), using reservoir simulators, can determine best-fit values for fracture compressibility, a key parameter for reservoir models. Finally, these data, along with DFIT reservoir pressure and permeability data, can inform the decision-making process regarding the most applicable completion strategy and aid developmental planning. For areas where vertical or surface-to-inseam (SIS) wells have been unsuccessful, new hydraulic fracturing technologies have been developed to enhance the stimulated reservoir volume (SRV) in coals, using horizontal wells with multi-stage hydraulic fracturing in excess of 20 stages. Recent laboratory and modelling of micro-proppants has extended prior laboratory and modelling studies and provided insight into proppant transport, embedment, and screen-out behaviour. These well stimulation technologies can be co-applied in new or existing CSG fields and are suitable for areas where overlapping tenements limit conventional, steel-based completion strategies. In conclusion, this paper will bring the key findings of these studies together in a cohesive framework and provide the workflows to implement these technologies for better productivity in low-permeability coals. To access the Oral Presentation click the link on the right. To read the full paper click here
Engineering Visual Presentation E04: Predicting ground surface deformation induced from CO2 plume movement using machine learning
Authors: Ibrahim Ibrahim M.
Published: June 2024

Engineering Visual Presentation E04 Carbon capture and storage (CCS), which involves injecting carbon dioxide (CO2) into subsurface, is an increasingly popular process for mitigating human caused greenhouse gas emissions. In order to ensure the safety and efficacy of CCS implementation, it is necessary to possess a comprehensive understanding of the complex behaviour of CO2 plumes within geological formations and their potential impact on ground surface deformation. Therefore, conducting research and analysis on these critical aspects is of vital importance. This research provides a methodology to anticipate ground surface deformations, which result from the motion of CO2 plumes utilising an advanced machine learning (ML) technique. The ML surrogate model has been developed using conditional Generative Adversarial Networks (cGAN). The dataset used for the model training and testing comprises ground surface measurements (tiltmeters), reservoir properties, as well as pressure/volume data. The model has been trained and tested using a set of samples created using a forward finite element model. Results show that the surrogate model is capable of predicting reasonably accurate results while running much faster than the forward model. To access the Visual Presentation click the link on the right. To read the full paper click here
Session 6. Oral Presentation for: Bayesian inversion of tilt data using a machine-learned surrogate model for pressurised fractures
Authors: Salimzadeh Saeed
Published: June 2024

Presented on Tuesday 21 May: Session 6 We introduce an innovative inversion approach for deducing subsurface fractures through observations of ground surface tilt. We have constructed, evaluated, and applied a surrogate forward model, crafted using conditional Generative Adversarial Networks (cGAN), to forecast the tilts (displacement gradients) at the ground surface caused by subsurface fractures under pressure. Our findings indicate that this surrogate forward model accurately estimates the tilt vector at the surface resulting from the specified pressurised fracture. Even in complex scenarios involving multiple fractures at various depths, the model, which was initially trained on scenarios with single fractures at a fixed depth, performed well. Subsequently, we employed a Bayesian inversion algorithm to derive the optimised solution (the pressurised fracture) for a given set of surface tilt data, leveraging the surrogate forward model. The outcomes demonstrate that the inversion process with the surrogate model is both effective and significantly faster compared to the traditional finite element model that generated the training data. To access the Oral Presentation click the link on the right. To read the full paper click here
Session 7. Oral Presentation for: The bystander approach to prevention
Authors: Orugun Bukkie
Published: June 2024

Presented on Tuesday 21 May: Session 7 In 2018, the Australian Human Rights Commission identified that in 40% of sexual harassment cases at least one other person witnessed the incident, and that in most of those incidents (69%), bystanders did not intervene. The oil and gas sector has normalised stop work and intervene as a workplace health and safety practice. What if, as an industry, our workforce was as confident and capable in intervening in harassment as they are when witnessing risks to physical safety? At MATE (Motivating Action Through Empowerment, Griffith University), we believe that change starts with the individual. Our training is based on the idea that not only do we have an opportunity to do the important work around raising the bar on acceptable behaviour, we have a responsibility. It is the work we do at an individual level with our peers that has a ripple effect on the people within our sphere of influence and ultimately makes the difference. This is the philosophy that underpins our approach to creating respectful workplaces. We help to develop effective leaders who have the tools to action change within our workplaces and our greater community. Since 2022, TechnipFMC Australia’s STRIVE (Supporting TechnipFMC to Reach Its Vision of Equity) team has been working closely with MATE to roll out a training package to its workforce, building an understanding of the role of the bystander in creating a safe and respectful workplace. The content will explore the benefits of active bystander behaviour, why TechnipFMC sees value in investing in the program and the impact of the program post-session. To access the Oral Presentation click the link on the right. To read the full paper click here
Session 7. Oral Presentation for: Reducing risk of sexual harassment: a positive duty of care
Authors: Shaw Elizabeth
Published: June 2024

Presented on Tuesday 21 May: Session 7 The oil and gas sector has made progress towards becoming safer and more respectful for all employees. However, recent public reports, including the Western Australian Parliament’s ‘Enough is Enough’, and increasing engagement from National Offshore Petroleum Safety and Environmental Management Authority (NOPSEMA), continue to demonstrate that sexual harassment remains pervasive across the industry – 32% of people still experience sexual harassment in their workplace. The social, physical, psychological, and financial costs of sexual harassment are devastating, both to individuals and employers. The damage can carry long-term business and reputational consequences. All Australian employers are under a new, legally enforceable positive duty to take ‘reasonable and proportionate measures’ to prevent sexual harassment. It requires proactive steps to ensure sexual harassment is prevented from happening in the first place. Vicarious liability provisions have been expanded so that employers can now be held accountable – even if no complaints are lodged. Employers require a clear framework to ensure they are meeting their positive duty obligations. There are three key areas that can enable the oil and gas sector to strategically leverage their compliance activities, maximising benefits for their business and for their people. These key areas include: (1) capability and engagement of leaders and management; (2) understanding the risk factors and drivers of sexual harassment for the industry, and for individual organisations; and (3) understanding employee experiences of psychological safety, culture, and behaviours. To access the Oral Presentation click the link on the right. To read the full paper click here
Session 8. Oral Presentation for: Are Australian carbon prices sufficient to support decarbonisation in gas production?
Authors: Wong Daniel Lorng Yon
Published: June 2024

Presented on Tuesday 21 May: Session 8 Recent years have seen a rapid increase in the push for energy transition in Australia. Carbon prices have been introduced through the Safeguard Mechanism and Australian Carbon Credit Units. Consumers of hydrocarbon products are beginning to demand carbon neutral products. Oil and gas operators are pledging net-zero emissions targets. The decarbonisation efforts that ensue are expected to drive a paradigm shift in upstream development approaches. In this work, we investigate how an anonymised high carbon dioxide (CO2) gas field may be developed under prevailing carbon prices. We identify three project archetypes and estimate economically recoverable resources under each project; we also analyse the economic performance of each project. In the first archetype, we consider a project where CO2 is separated from the produced gas and vented into the atmosphere. In the second archetype, we consider a carbon sequestration project in which CO2 is transported via pipeline for storage in an onshore depleted gas reservoir. Lastly, we consider a case in which the gas buyer demands a fully carbon neutral product; as such, we study the feasibility of producing blue hydrogen using the produced gas, and how this impacts project economics and reserves. The case studies quantify by how much decarbonisation efforts negatively impact project economics and how they are the least objectionable when carbon prices are high. The analysis shows that carbon prices in Australia are currently sufficient to enable commercial development in ideal situations, but need to be higher to enable wider decarbonisation. To access the Oral Presentation click the link on the right. To read the full paper click here
Session 8. Oral Presentation for: Commercialising carbon capture and storage – how much does regulatory certainty truly matter?
Authors: Mahapatra Polly , Creswell Rob
Published: June 2024

Presented on Tuesday 21 May: Session 8 With carbon capture, utilisation and storage (CCUS) technology advancement reaching a point of scalability, there is a desperate need for global regulatory and legislative frameworks to support large-scale commercialisation. With various economies at differing stages of updating their policy and regulatory frameworks, the impact on investment into large-scale CCUS projects is an area worth interrogating to understand whether regulatory certainty has material impact on viability of a CCUS project, or whether the bulk of the project economics are still driven by traditional cost components. This paper seeks to undertake a literature review of current regulatory and policy frameworks such as the US Inflation Reduction Act 2022 and Australia’s Safeguard Mechanism to undertake a relative comparison of the two leading regulatory policies on large-scale carbon capture and storage. This paper will also undertake a comparison of a theoretical large-scale carbon capture and storage project subject to each type of regulatory condition to estimate the potential impact on project viability in each scenario. The aim of the paper is to understand the magnitude of impact that regulatory policies can have on commercialisation of a large-scale CCUS project. To access the Oral Presentation click the link on the right. To read the full paper click here
Session 10. Oral Presentation for: Gross depositional environment mapping in the onshore South Australian Otway Basin: an example of data integration
Authors: Cubitt C.
Published: June 2024

Presented on Wednesday 22 May: Session 10 As part of a greater petroleum systems modelling project, gross depositional environment maps were made for six key intervals in the onshore portion of the Jurassic to Late-Cretaceous Otway Basin in South Australia. This mapping interpreted varied depositional systems including anoxic, extensive ice-influenced lacustrine, lacustrine turbidite, extensive fluvial/lacustrine, fluvial/flood plain and growth fault-bound ribbon-like alluvial fan aprons. To access the Oral Presentation click the link on the right. To read the full paper click here
Session 13. Oral Presentation for: Alternative application of availability and deliverability studies to reduce the energy sectors’ carbon emissions
Authors: Lawrenz Helge , Mahdianfar Hamed
Published: June 2024

Presented on Wednesday 22 May: Session 13 The objective of the paper is to present the advantages of utilising reliability, availability and maintainability (RAM) studies as a decision-making tool for the deployment of carbon capture and storage (CCS), by providing detailed and quantifiable CCS rates of the analysed design concept. The study used methodology to predict carbon capture rates with high confidence for several compression and dehydration train design concepts. This allowed the operator to make decisions on the most cost-efficient design, while having a confident understanding of the design-specific carbon capture potentials. The most favourable CCS concept was combined with the existing liquefied natural gas plant RAM model and production profile for a detailed analysis of remaining daily carbon dioxide (CO2) venting rates as a result of potential CCS outages. The RAM models are based on generic and proven reliability data and include a level of detail that ensures a very reliable prediction of exact carbon capture rates. Besides analysing and comparing the design concept results as system availability, the CCS concept was analysed for its carbon capture deliverability. This provided the operator with a high confidence of average as well as monthly CO2 capture and venting rates for selected CO2 production profiles. The application of RAM for CCS and other energy sustainability projects has proven to be a powerful tool, allowing operators to make informed decisions towards achieving net-zero efficiency. Providing operators with an accurate and long-term prediction of their carbon footprint, when analysed in combination with their energy portfolio. To access the Oral Presentation click the link on the right. To read the full paper click here
Session 17. Oral Presentation for: Energy efficiency as an accelerator to environmental and operational performance
Authors: Scott Stuart
Published: June 2024

Presented on Wednesday 22 May: Session 17 As oil and gas operators continue to enhance and start implementing their plans to meet their regulators’ and customers’ net-zero related demands, the industry should not overlook those low-hanging fruit that will bear results in the short term and, if done well, also contribute to long-term objectives. An effective approach to energy management will contribute to environmental, operational and financial outcomes, by addressing resource scarcity and price volatility, delivering on licence-to-operate considerations, complying with regulations, and delivering a competitive advantage through greater efficiency and enhanced reputation. Key considerations are as follows. Data quality: fuel, power, steam, condensate balances will highlight data gaps and inconsistencies. Energy usage: inefficiencies in operations such as boilers, turbines, as well as systemic issues, such as cycle efficiency and steam and condensate losses, can be identified. Emissions monitoring and reporting: clear and consistent data about fuel and power consumption directly feeds into greenhouse gas corporate reporting schemes. Quality assurance of monitoring and reporting processes: review and challenge dashboards and reports for completeness, accuracy and clarity. Management operating system: redesign management processes to improve workflows and optimise operations. Loss accounting: Production and Energy Loss Accounting (PELA) improves staff collaboration and effectively tackles hidden losses. In this paper, dss+ will share how, using a mix of operational efficiencies and capex, an integrated oil and gas company active in 30 countries identified potential to reduce its emissions by 38 m tonnes of CO2 leading to over US$6 m in savings per annum over 4 years for just four of its assets. To access the Oral Presentation click the link on the right. To read the full paper click here
Session 18. Oral Presentation for: Requalification of pipelines for CO2 transport – giving new life to the Bayu-Undan and Reindeer pipelines
Authors: Lim Nigel
Published: June 2024

Presented on Wednesday 22 May: Session 18 Australia has in the order of 3500 km of offshore pipelines currently operating in Commonwealth waters which will require either re-use or decommissioning at the end of hydrocarbon service. Santos are currently developing the Bayu-Undan and Reindeer CCS (carbon, capture and storage) Projects, to make use of the depleted hydrocarbon reservoirs to store carbon dioxide (CO2) via existing offshore infrastructure. A key aspect of these projects is the requalification of existing offshore hydrocarbon pipelines to transport CO2, both of which have been in operation for 10–20 years. The Bayu-Undan and Reindeer pipelines were designed and operated for (a) distinctly different hydrocarbon services and (b) with no initial consideration for future CO2 service. This presents two unique technical starting points in the delivery of safe and robust conversion to CO2 service. Using knowledge gained from this, the paper provides an outline of the key technical considerations to requalification of pipelines unique to the combination of life extension and CO2 service. These are framed in the context of existing industry codes and technical challenges with CO2 pipelines. The outcomes are structured against typical phases in the project lifecycle and opportunities for optimisation of future CO2 re-purposing projects are proposed. To access the Oral Presentation click the link on the right. To read the full paper click here
Session 19. Oral Presentation for: The Rafael gas-condensate discovery – a potential game-changer in the Canning Basin
Authors: Chambers Kurt
Published: June 2024

Presented on Wednesday 22 May: Session 19 The Rafael 1 exploration well discovered an abnormally high-pressured gas condensate pool in the Kimberley region in late 2021. Data supports a minimum gross gas column of 165 m at the well location trapped within a large faulted four-way closure in a dolomite reservoir sequence with strong similarities and age equivalent to the oil-bearing Ungani Dolomite reservoir in the Ungani Field. A successful production test in March 2022 resulted in sustained natural flows of gas and condensate to surface. The presence of thick sandstones of the Anderson Formation and a complete Laurel section beneath the Meda Unconformity were unexpected based on the pre-drill interpretation. Serendipitously, it provided the perfect geological setting for a significant hydrocarbon accumulation and emphasised the need to consider multiple geological scenarios when evaluating prospects to capture the full range of uncertainties and potential pool sizes. Although the range in size of the contingent resources is wide and requires further drilling for refinement, the Rafael 1 discovery could be one of the most significant onshore gas discoveries since Waitsia 1 and provides impetus and incentive for continued exploration in the basin. Several pathways for commercialisation have been identified linked to the resource size. A comprehensive appraisal program is underway including the recently completed acquisition of a 200 km2 3D seismic survey to optimally locate wells, and plans for drilling to reduce uncertainty and support the first phase of development based on a low case contingent resource that could underpin the energy needs of the Kimberley region. To access the Oral Presentation click the link on the right. To read the full paper click here
Session 19. Oral Presentation for: A Mesoproterozoic (~1.25 Ga) ‘fossilised’ oil column in the Moroak Sandstone of the Beetaloo Sub-basin, NT
Authors: Kempton Richard
Published: June 2024

Presented on Wednesday 22 May: Session 19 The Beetaloo Sub-basin hosts a large unconventional ‘shale gas’ resource within organic-rich Mesoproterozoic shales of the Velkerri and Kyalla formations; however, little has been done to understand conventional oil charge to the associated sandstone reservoirs. Using Grains containing Oil Inclusions, we show that an ancient ‘fossilised’ oil column once existed at the top of the Moroak Sandstone in the Elliott-1 well. The column had a minimum height of 18.02 m, with a possible paleo–oil–water contact at the base of a resistive zone on logs at ~1348 m and a change in core colour. Fluid inclusion oil is entrapped in quartz cement and is inferred to be a light oil of >42°API gravity from its near-blue fluorescence colour. Post-oil solid bitumen is still present in the reservoir sandstone, and we assert that this helped to retard the crystallisation of quartz cement that elsewhere occluded porosity. From burial history models that utilise a refined source rock maturity evaluation method, we claim this to be the remnant of Australia’s oldest yet known conventional oil accumulation at ~1.25 Ga. Analogous bituminous paleo-reservoirs from the North China Craton, dated at 1327 ± 2 Ma, were likely sourced from similar oil-prone cyanobacterial shales that formed during their shared connection with the North Australian Craton on the ancient supercontinent Nuna during the Mesoproterozoic. To access the Oral Presentation click the link on the right. To read the full paper click here
Session 20. Oral Presentation for: Decommissioning and restoration: early planning is critical to an efficient and risk-minimised process
Authors: Reinders Jankó
Published: June 2024

Presented on Wednesday 22 May: Session 20 Over the next 7 years, according to Wood Mackenzie, it is estimated that as many as 380 fields oil and gas facilities will be decommissioned across Asia–Pacific (Wood Mackenzie 2018). Many companies leave Decommissioning and Restoration (D&R) up to the respective project groups using their normal project management and control systems. However, managing D&R requires a different approach and mindset, as the value drivers and risk profiles for D&R projects are different compared to conventional construction projects. For D&R to be efficient – from operational, sustainability, regulatory compliance, environmental and financial perspectives – delivery must not be limited to an isolated project group. Rather, it must leverage corporate and operational knowledge, lessons learned from other decommissioning projects and industry best-practice to support the identification and management of the decommissioning risk profile and successful delivery thereof. Planning for D&R is essential at every stage of the life of an asset and should start as early as possible. Ideally, facilities are designed with D&R in mind at the project conception stage as the scope of D&R is often broader and more complex than operators realise, contributing to D&R projects often exceeding original cost estimates and timelines. Decommissioning and restoration opportunities may be missed or associated risks increased without timely recognition and management. In this paper, dss+ will provide companies with pragmatic guidance on how to plan and implement a D&R process that is managed well from an operational, risk, financial, contractor management and importantly, a stakeholder management point of view. To access the Oral Presentation click the link on the right. To read the full paper click here
Session 22. Oral Presentation for: Transitioning a hydrogen facility from project to operations
Authors: Chrisfield Gregory J.
Published: June 2024

Presented on Wednesday 22 May: Session 22 Preparing any hazardous facility for transition from project to operations requires a rigorous management process. In the area of hydrogen operations, hazards are heightened and there are limited examples of transitioning a hydrogen facility from project to operations outside of large-scale oil refineries. This paper highlights the unique challenges of managing hydrogen process safety through the project to operate phase while maintaining safety standards that meet or exceed the expectations of the asset owner, regulator and the community in which we operate. Our experience transitioning hydrogen operations started in Queensland which has arguably the toughest engineering and safety standards in Australia. This experience has informed our methodologies and the important points of this paper detail for both owner and regulator, what to expect from the operator and what the operator will need to demonstrate compliance with. Hydrogen operations traditionally were on oil refineries which may have been in local communities, unlike remote upstream gas and oil projects far from the major populations. Refineries are typically close to transportation hubs and end users. Our experience is that hydrogen or hydrogen transport fluids such as ammonia, methylcyclohexane (MCH) and others are more likely to reside near major international ports with close access to both clean energy and available workforce which heightens the environmental, social, governance and community risk management requirements. This paper intends to inform regulators, owners and operators of the unique challenges and aspects of getting a hydrogen facility up and running in a safe and community sensitive way. To access the Oral Presentation click the link on the right. To read the full paper click here
Session 22. Oral Presentation for: New dog old tricks – process safety for the energy transition
Authors: Stembridge Alice
Published: June 2024

Presented on Wednesday 22 May: Session 22 The energy transition is gathering pace and it’s apparent there is not one solution to replace our traditional means of sourcing energy from fossil fuels. The energy transition embraces renewable power generation, whether in the form of solar, wind, hydro or using waste materials and plant feedstocks such as biomass to produce fuels of the future. There is a colourful range of hydrogen solutions in grey, blue or green available, with blue requiring a carbon capture and storage solution. The solutions being considered for the energy landscape are on a scale not seen before. All of these new energy solutions have one thing in common, they present known hazards, but the application and simple scale of their use is significantly greater than when they are produced or consumed today. When we discuss renewable energy, it is perceived that generally it is safer than sourcing and processing conventional energy forms. Conventional fuels have a long history of process safety and have been well regulated for more than 20 years as major hazard facilities. The expectations of communities and regulators are that renewable energy will be delivered reliably and safely and to the same standard as conventional energy forms. We call this process safety equivalency. We will examine a few areas as examples of some of the early problems being addressed and solved today. To access the Oral Presentation click the link on the right. To read the full paper click here
Session 26. Oral Presentation for: Neighbourhood watch: the future of Asian LNG demand growth
Authors: Ramesh Kaushal
Published: June 2024

Presented on Thursday 23 May: Session 26 The global liquefied natural gas (LNG) market has returned to a semblance of calm after a tumultuous 2022. European and Chinese demand is on the path to a slow recovery, while a nuclear power renaissance is underway in Japan and South Korea. This paper will detail our expectations for LNG demand growth, discuss demand drivers and market development opportunities for Australian LNG between the late 2020s to early 2030s. We see LNG demand in the region increasing from 260 Mtpa in 2023 to 479 Mtpa by 2035. The largest source of growth continues to be China with demand growing from 68 to 150 Mtpa, driven by uptake of LNG in the industrial and buildings sectors. We will also see South Asian demand growing from 33 to 100 Mtpa, and Southeast Asian demand from 24 to 103 Mtpa. Even in legacy markets of Japan and Korea where we see demand declining in this timeframe, we will see the emergence of new buyers and the impact of market liberalisation measures. The expiry of legacy contracts and the rising influence of US LNG is set to complicate market dynamics further. We discuss the challenges of the energy transition in a region that must balance emissions considerations with energy demand. We conclude that Australian projects with their proximate location and legacy relationships will remain an attractive proposition for Asian buyers. Ullage at existing LNG plants will support backfill economics, with decarbonisation measures taken under the Safeguard Mechanism demonstrating genuine emissions reduction action. To access the Oral Presentation click the link on the right. To read the full paper click here
Session 26. Oral Presentation for: Australia–Japan energy partnerships for regional security and decarbonisation
Authors: Koravos Celeste
Published: June 2024

Presented on Thursday 23 May: Session 26 Australia and Japan stand at a pivotal juncture in their energy futures, with shared imperatives of ensuring energy security, affordability, and sustainability. As key players in the global energy landscape, their collaboration holds the potential to shape the trajectory of the Indo-Pacific’s energy transition, as outlined in Japan’s ‘New Plan for a Free and Open Indo-Pacific’ (FOIP). A central aspect of this collaboration involves securing liquefied natural gas (LNG) supplies from Australia to Japan and the region while simultaneously decarbonising the supply chain through carbon capture and storage (CCS) and advancing hydrogen technologies. Both nations recognise the significance of natural gas in ensuring regional energy security and affordability. Japan, heavily reliant on energy imports, particularly LNG, is motivated by past crises and geopolitical tensions to diversify its energy sources. The partnership between Australia and Japan not only addresses Japan’s energy needs but also influences the power dynamics within the Indo-Pacific. Challenges such as regulatory uncertainties and policy shifts dampen confidence for Japanese investors in Australia’s energy sector. Despite this, CCS technology offers a promising pathway to reduce emissions from natural gas production, with infrastructure facilitating low-emission hydrogen production. Policy coherence and streamlined regulations are essential to fostering innovation and scaling up these technologies. Collaboration on CCS and hydrogen commercialisation presents opportunities for both nations to lead the energy transition. Japan’s ambitious plans to increase its domestic hydrogen supply highlight the potential for joint efforts. To access the Oral Presentation click the link on the right. To read the full paper click here
Session 27. Oral Presentation for: Development of long-distance and large-scale carbon capture and storage (CCS) value chain using liquefied CO2 ship transportation
Authors: Cha Daein
Published: June 2024

Presented on Thursday 23 May: Session 27 Carbon capture and storage (CCS) is central to clean energy transition. Globally, potential aggregated carbon dioxide (CO2) storage resource capacity is ~13,000 billion tonnes. Assuming global greenhouse gas emissions of 51 billion tonnes per annum, CO2 storage capacity equates to 250 years of global emissions reduction. While there is significant momentum to deploy CCS technology for meeting Paris Agreement targets, the key challenge for offering CCS to all industrial sectors is that many major CO2 emission sources are located hundreds of kilometres away from geological storage sites. To address this key challenge, there is a need to develop a long-distance and large-scale CCS value chain that utilises liquefied CO2 (LCO2) ship transportation. This paper discusses key technical, commercial, and regulatory considerations that must be addressed in parallel for developing such a CCS value chain. More specifically, it will cover the following: (1) technical – CO2 liquefaction condition, CO2 supply specification and LCO2 ship parcel size; (2) commercial – business model (ownership of CO2 retained by emitters or transferred to CCS project proponent), CO2 supply or CCS facility lease terms and conditions; and (3) regulatory – domestic versus transboundary projects and associated needs for policy and legislative underpinning. To access the Oral Presentation click the link on the right. To read the full paper click here
Session 27. Oral Presentation for: The Bayu-Undan liquid CO2 import facilities – finding an effective solution
Authors: Weiter Ross
Published: June 2024

Presented on Thursday 23 May: Session 27 Carbon capture and storage (CCS) is widely considered to be one of the key enablers to decarbonising the economy. It is currently being implemented in a number of projects in gas, power, chemicals, cement, steel, and other industries. In the Asia–Pacific region, shipping of liquid carbon dioxide (LCO2) is widely seen as a key component of the CCS value chain. Shipping allows the emitters located in the industrial centres of Japan, Korea, and Singapore to access distant CO2 storage locations. The repurposing of the Bayu-Undan (BU) platforms and pipeline from gas production to CO2 injection presents a regional opportunity for the disposal of shipped CO2. Multiple LCO2 development concepts were assessed for unloading and storing the imported LCO2. Unloading can be carrier-to-shore, carrier-to-ship/barge, or carrier-to-platform; storage can be onshore, nearshore, offshore or no buffer storage at all with direct injection from carriers. These concepts required evaluation for technical functionality, maturity, complexity, operability, and availability. Imported LCO2 is too cold and low pressure to be transported or injected at the carrier transport conditions. The pressure needs to be boosted and temperature increased to meet the requirements of the injection system. This requires sources of power and heat. An evaluation of existing facilities, their condition, available space and spare capacity, and their constructability considerations revealed important opportunities and constraints. A study was carried out, which evaluated options for the BU LCO2 import using key evaluation criteria to select the most appropriate concept. This paper explores addressing the challenges involved. To access the Oral Presentation click the link on the right. To read the full paper click here
Session 27. Oral Presentation for: The potential for CO2 storage in residual oil zones in onshore Australian basins
Authors: Kalinowski Aleksandra
Published: June 2024

Presented on Thursday 23 May: Session 27 Geoscience Australia and CSIRO have collaborated to investigate whether residual oil zones (ROZs), sometimes associated with conventional Australian hydrocarbon plays, could provide a carbon dioxide (CO2) storage resource and enhance the storage capacity of depleted fields. Our petrophysical study demonstrates that ROZs occur in Australia’s hydrocarbon-rich regions, particularly in the Cooper-Eromanga Basin. ROZs with more than 10% residual oil saturation are uncommon, likely due to small original oil columns and lower residual saturations retained in sandstone reservoirs than in classic, carbonate-hosted North American ROZs. Extensive, reservoir-quality rock is found below the deepest occurring conventional oil in many of the fields in the Eromanga Basin, potentially offering significant CO2 storage capacity. Multiphase compositional flow modelling was used to estimate the CO2 storage efficiency of typical Australian ROZs. We developed a novel modelling methodology that first captures oil migration events leading to the formation of ROZs. Modelling CO2 storage over a 20-year injection period demonstrates that CO2-oil interactions increase the density and viscosity of CO2, enhancing CO2 sweep efficiency and lateral flow, improving storage efficiency. The extent of these effects depends on the quantity and spatial distribution of residual oil in place and the miscibility of CO2 at reservoir conditions. To access the Oral Presentation click the link on the right. To read the full paper click here
Emission Reductions Visual Presentation R03: Megawatts to methane – a deep drop in emissions reduction transition for existing regional gas-based ammonia plants
Authors: De Boer Jacob
Published: June 2024

Emission Reductions Visual Presentation R03 Synthetic ammonia production sustains food production for more than half of the world’s population. Many regional ammonia plants convert all ammonia to ammonium nitrate fertiliser. With these, all carbon in the feed ends up as carbon dioxide (CO2), with around 2 tonnes of CO2 released per tonne of ammonia produced using natural gas. Conveniently, ammonia plants produce a substantial pre-concentrated CO2 stream. Ammonia plants are high-capex, long-life assets that operate for 40+ years. With the energy transition, replacing such assets is very high cost and will dramatically impact the cost of food production. Further, green energy is highly variable, leading to the need for additional supply side assets to stabilise energy supply. This paper outlines a transition approach for a 30% CO2 reduction (also a 43% case) to extend the useful life of these assets while re-using much of the plant, with the ability to turn on/off the green energy with minimal disruption for stable operation. The example plant is based on a typical 750 tpd ammonia gas Steam Methane Reforming (SMR) plant. The approach considers adding and integrating green power and biogas into this plant to reduce net reportable CO2 emissions. Methanation of CO2 has been demonstrated in several projects and is considered key in developing a transition pathway for an existing gas-based plant, extending its operational life and flexibility to operate with varying degrees of variable green energy supply. Further, whilst Synthetic Natural Gas (SNG) is used in this case, the approach can be beneficially applied with methanol and other Power-to-X opportunities. To access the Visual Presentation click the link on the right. To read the full paper click here