Dam decommissioning: old dams, new opportunities

While many dams have very long lives, and could in theory operate for centuries, some dams reach a point at which decommissioning becomes a realistic final phase of the dam life cycle.

Decommissioning is not something that happens very often, given the significant value of dams and their functions, which are often multiple. Maintaining and upgrading dams, rather than decommissioning, can sometimes also be a more sustainable solution if this extracts more economic, social and environmental value to offset the initial impacts that the dam may have caused when originally constructed.

However, decommissioning may be the best option if the dam is no longer needed to deliver its original purpose, if it is no longer providing commercial or societal benefits, or if it is considered too costly to continue maintaining the dam or to undertake the necessary upgrades to stay compliant with contemporary regulations and standards.

How is a decision to decommission made?

The decision to decommission a dam is usually based on a comprehensive risk assessment. Risk assessments play a critical role in managing dams throughout their life cycle. They primarily focus on ensuring safety and minimising risks associated with dam operation, failure and decommissioning.

Risk assessments estimate risks, identify hazards and failure modes, evaluate the tolerability of the risk, compare potential risk reduction measures if needed, and establish a risk reduction strategy.

If the risk is not tolerable, risk reduction measures will be recommended, and a risk reduction strategy will be established to reduce the risk. The risk reduction measures will generally involve upgrade works. When the option to undertake dam upgrade works is considered, the option to decommission the dam is often also included. The dam owner can then undertake a cost–benefit analysis to determine the most viable option, understand the level of risk reduction achieved, and consider less tangible aspects such as community concerns.

What’s involved in decommissioning a dam?

Decommissioning a dam requires considerable planning to minimise environmental impacts and reduce the chance of leaving any residual hazards in the long term. A thorough assessment of the site conditions and downstream environment is a crucial first step towards identifying the appropriate decommissioning actions.

The location of the dam and the details of the dam works will determine the planning requirements, which often include:

• engineering design – taking breach width and batters into account to remove the possibility of retaining water, and assessing the impact on flooding downstream (as dams frequently provide flood mitigation even when this is not their primary function)
• sediment and erosion control planning – as sediment release can cause significant water quality issues and harm to habitats downstream. It is important to note that the reservoir area will initially be unvegetated and will not have any topsoil that can be used to support vegetation growth to control erosion. Additionally, sediments will typically have been deposited in the dam reservoir and are generally very easily remobilised, so this needs special attention from the designers
• flora, fauna and cultural heritage studies – as decommissioning can dramatically alter ecosystems both upstream and downstream, and heritage features can often be highlighted improving the amenity of the new asset. Ecological studies such as flora and fauna assessments are important to identify any threatened species that need to be considered in the decommissioning plans, such as through exclusion zones or timing the works to minimise impacts (e.g. conducting work outside of breeding seasons)
• fluvial geomorphology assessment – which identifies how rivers interact with their landscapes and how they change over time. It is important to understand this given that the decommissioned dam will have water flowing through it rather than retaining water, changing the balance of erosion and sedimentation processes
• dam safety emergency plan for decommissioning works – to protect communities from flooding during the decommissioning works
• regulatory approvals – a dam decommissioning permit will be needed, which will include managing any specific regulatory requirements such as issuing a notice of intent prior to commencing works and providing work-as-executed reports and drawings at the completion of the works to confirm all conditions have been successfully met.
• Depending on the use and location of the dam, it is recommended to consult with a range of stakeholders, including the local community and council, during the planning process to ensure that their perspectives and concerns are considered early. If the dam is located near to residences, public spaces or other civic amenities, extensive consultation is likely to be needed due to the potential nuisance from the works (e.g. noise, dust and additional traffic in the local area). A masterplan can be developed through this process of consultation, outlining potential options for remediating and repurposing the area based on the community’s priorities, such as creating potential new community assets such as wetlands, parks or sporting facilities.

The work involved in decommissioning a dam will depend on the type of dam and the surrounding environment but commonly involves:

• re-routing inflow away from the reservoir or past the dam
• removing all or part of the dam wall
• modifying or removing the outlet works
• lowering the spillway crest level or removing the spillway control gates or stop-boards
• treating retained liquid prior to discharging it in a safe condition
• stockpiling and stabilising accumulated sediments from within the reservoir
• removing or encapsulating impounded material, such as trees and vegetation
• revegetating the reservoir area and rehabilitating the site to perform its new purpose.

Doing it safely

Decommissioning a dam is a very complex matter involving many stakeholders and often taking some time to reach its conclusion, so it is prudent for dam owners to embark early on some interim measures to rapidly reduce any identified dam safety risks. The simplest and most cost-effective risk reduction measure is usually to lower the level of the reservoir.

The next stage is identifying the planning requirements and works involved with decommissioning and developing a decommissioning plan. The engineering design, included in the decommissioning plan, will consider the necessary environmental assessments and ensure adherence to appropriate guidelines.

Common considerations when developing the engineering design include:

• hydrological and hydraulic assessment of conditions before and after decommissioning
• the necessary breach width and batters to make the site safe
• safely discharging or removing retained water and material
• the volume of any attenuated water remaining after decommissioning
• gradient of the land if the reservoir is being completely drained
• erosion and sediment control during and after decommissioning
• managing inflows and floods during the decommissioning
• careful consideration of the final land use after decommissioning including the ecological restoration and community uses.

Achieving success

For decommissioning to be considered successful, it’s crucial that the decommissioning plan and engineering design take account of the priorities that emerge from stakeholder consultation. Many communities become attached to a dam as part of their local landscape, especially if the dam is very old. They may wish for some of the dam’s heritage to be retained or acknowledged in some way, such as retaining and integrating parts of the abutment into the future form or land use where it is safe to do so, or echoing the past by incorporating smaller water features into the resulting site.

Another major consideration for successful decommissioning is controlling erosion and sediment. Reservoirs typically have a low point that can function as a temporary sediment basin once the water level is substantially lowered. Rainfall and inflows can be channelled with small bunds and hessian silt rolls to the sediment basin. Turbid water can then settle or be treated, if necessary, before being pumped out. After decommissioning, erosion and sediment can be managed by revegetating exposed areas with native plants, creating habitat features such as wetlands or log jams, and managing and monitoring wildlife to ensure their adaptation to the changing environment. Simple solutions can be implemented to achieve positive – or at least neutral – outcomes for biodiversity.

Right process, right people

Decommissioning dams takes a wide range of skills to deliver a successful outcome – from hydrology and hydraulics, environmental and heritage assessments, through to detailed construction planning and a vision for the repurposed land. With the right people and process, decommissioning can reduce safety risks to the community, protect the environment during the works, and ultimately create new, sustainable assets enhancing the amenity of the area for the benefit of communities now and long into the future.

Entura has been involved in a number of dam decommissioning projects including Waratah Dam and Tolosa Dam. To talk with Entura’s specialists about a dam decommissioning project, contact Richard Herweynen or Phillip Ellerton.

ABOUT THE AUTHOR

Joey Scicluna is a civil engineer, who began his career managing commercial and subdivision projects. Since joining Entura’s dams and geotechnical team in 2022, he has undertaken a wide range of dam safety surveillance inspections and reporting, dam safety modelling and analysis and risk assessments. Joey has been the lead author for a number of intermediate and comprehensive dam safety reviews, and has developed design concepts and conducted feasibility studies for existing and new dams projects. Joey enjoys problem solving and working with stakeholders to achieve the best outcome for every project.

Risk is the word – reflections on the NZSOLD/ANCOLD 2025 conference

From 19 to 21 November 2025, industry experts from consultants to asset owners gathered in Ōtautahi Christchurch, New Zealand, to exchange insights, challenge thinking and strengthen connections ‘across the ditch’ and beyond. Here Entura’s Sammy Gibbs reflects on the conference …

If I had dollar for every time I heard the word ‘risk’ across the two-day event, I might have been able to fund next year’s conference myself!

Why was this the case? As noted in many of the presentations and papers, the dam industry is facing the combined challenges of aging dam infrastructure, changing design standards, climate change impacts, community expectations and resource/cost constraints. As a result, the industry is shifting more towards risk-informed decision-making/frameworks, compared to traditional standards-based approaches,to manage and design dam infrastructure.

No dam is 100% safe and all risks can never be designed out entirely, but a sophisticated understanding of their risk can inform our decisions and actions so that we can target key issues cost-effectively and ensure resilience in our dams and water infrastructure.

Risks in asset ownership

In his opening address, Andrew Watson, Director of Dam Safety & Generation Asset Planning at BC Hydro in Canada, provided valuable insights into how BC Hydro uses a risk-informed framework to manage its dams. He discussed the use of a ‘vulnerability index’ to understand the significance of identified physical deficiencies in the dam portfolio. The higher the index, the greater the likelihood that the deficiency would result in poor performance. This index allows BC Hydro’s dam safety team to understand the overall risk profile and prioritise future works. It left us contemplating how the ANCOLD 2022 Risk Assessment Guidelines and ALARP process may be enhanced by integrating components of this approach. This could be a useful way of measuring how far the dam is from meeting ‘best practice’ and hence enhance the justification for further risk reduction or accepting the position as ALARP.  

Later in the conference, Andrew Watson was joined by Peter Mulvihill, Lelio Mejia and Barton Maher to discuss legacy risk and how to manage it. Legacy risk is relevant for many asset owners (nationally and internationally) as our sector faces the complexities of inheriting aging facilities, acquired from past organisations/owners. A key challenge with these legacy structures is the transfer of knowledge to new asset owners. Important records such as monitoring data, design and construction information are often lost (or were never developed), making it difficult to understand and quantify the current risk position of the structure. These aging facilities are also unlikely to meet current design standards or withstand climate change impacts. Risk-informed decision making and phased approaches become critical in such instances, as does asking the question ‘Does it matter?’ when it comes to unknowns. Like tying surveillance programs to key failure modes, unknowns should also be associated with credible failure modes.

It was noted that for some of these structures the most appropriate solution is decommissioning, as the risk imposed by the structure (and the cost to mitigate it) may outweigh the economic benefit of the asset itself. In such instances, this decision can provide social and environmental benefits and are worth investigating.

Risk in surveillance monitoring

The conference reaffirmed the critical role of risk-based surveillance monitoring and the importance of understanding how dam instrumentation relates to key failure modes and/or performance. The most effective tool to support this is an event decision tree.

Entura’s Diego Real reiterated the importance of understanding key failure modes when implementing instrumentation upgrades. His paper presented a staged approach for the upgrades, providing clients with a cost-effective, practical solution that assists in managing dam safety risks.

Although there was discussion about various ways in which surveillance programs can be optimised, our industry is aligned in recognising the criticality of undertaking routine inspections as the first line of defence when it comes to identifying potential failure indicators.

Risk mitigation solutions

Several presenters shared examples of bespoke solutions responding to dam risks – including Entura’s Jaretha Lombaard, who highlighted how a Swedish berm was used to mitigate risks associated with piping failures at an earth and rockfill embankment dam in Tasmania.

Other risk mitigation solutions presented included non-physical works such as improvements in surveillance and monitoring. In one example, alarm systems in rivers are being used effectively to warn and evacuate the public in a swimming pool downstream in the event of a flood. Instead of relying solely on costly capital-intensive physical upgrades, the most effective strategy for reducing societal risks may lie in enhancing the speed and reliability of early warning systems.

Sharing knowledge to tackle similar problems

NZSOLD/ANCOLD 2025 was an excellent opportunity to see how specialists are tackling the complex challenges facing the dams industry. Walking away, my mind was full of phrases involving the word ‘risk’, but I felt reassured that we are all facing similar problems and by sharing our knowledge and innovations we’re continually improving our ability to design, monitor and maintain dams.

This conference will be a tough act to follow, but I look forward to the 2026 ANCOLD conference to be held in Lutruwita/ Tasmania (where I live and Entura originated).

ABOUT THE AUTHOR

Sammy Gibbs is a civil engineer with 7 years of consulting experience and joined Entura’s Dams and Geotech Team in May 2021. Sammy has a diverse background in dam and water engineering and works on a range of projects including consequence category assessments, hydrology studies, hydraulic design, risk assessments and dam design projects.

Reflections from MYCOLD 2025: Innovation, resilient dams and the evolving role of hydropower

Earlier this month, I had the privilege of joining colleagues from across Malaysia and the region at the 3^rd International Conference on Dam Safety Management and Engineering (ICDSME2025), organised by the Malaysia Commission on Large Dams (MYCOLD), held in Kuching, Sarawak. There’s a particular energy that comes with a MYCOLD conference – part reunion, part technical deep-dive, part regional conversation about water, resilience and community safety.

I returned energised and inspired – not only by the technical excellence on display, but also by the sense of shared purpose across our industry and the tangible people-to-people exchanges and collaborations. With energy systems transforming rapidly, climate change accelerating and dam safety expectations strengthening, it has never been more important for dam and hydropower professionals to share openly and learn from one another. ICDSME2025 offered that in abundance.

Here are just a few reflections on some of what I heard …

Reimagining hydropower in changing markets and climates

In the ‘Advancing sustainable hydropower’ session, I shared perspectives from Tasmania’s long hydropower journey and Entura’s experience supporting the state’s major renewable energy initiatives.

My message was clear: the feasibility of pumped hydro or of reimagining conventional hydropower isn’t simply a technical question of ‘can we build it?’ but ‘what is the long-term value it creates?’ Smart choices depend on a holistic understanding of context – i.e. the markets, energy mix, climate, environmental impacts and benefits, and community perspectives and impacts. Pumped hydro is never ‘impact-free’, and it is not inherently more sustainable than conventional hydropower. What matters is how we think about the future of the energy transition, understanding what role pumped hydro can play in that context, how well we select sites, how carefully we consider environmental and social impacts, and how thoughtfully we design (and extend) assets for long-term economic and social value.

With wind and solar dominating new energy investment in Australia, hydropower’s baseload role can shift to respond to evolving market dynamics. Hydropower’s deep storage, flexibility and system stability are becoming increasingly important. We’re seeing these opportunities in Tasmania, where both conventional hydropower and pumped hydro could – with more interconnection to the mainland – help balance a renewables-rich National Electricity Market while returning extra revenue to Tasmania and increasing the reliability of supply across Australia’s south-east.

Climate change adds further complexity to feasibility considerations. Changing rainfall patterns, more variable inflows and more frequent extremes – as well as with the increasingly variable generation mix and how energy sources interact – all influence when hydropower can generate or store.

Ultimately, I believe there are not only opportunities with extending operating life, refurbishing or redeveloping dam assets; there are also obligations upon us as an industry to do our best for the sustainability of these assets. We need to focus constantly on how to optimise outcomes from the base impacts of hydropower or dam developments and seek ways to reduce impacts into the future. We also need to think about how to deliver great outcomes and value that extends across a long asset life, beyond the limited commercial timeframes considered in final investment decisions.

Technology, people and the future of dam safety

I had the honour of chairing a keynote session featuring Yang Berbahagia Prof. Datin Ir. Dr. Lariyah binti Mohd Sidek and Dr Martin Wieland.

Dr Wieland’s insights into the seismic performance of dams reminded us that strong engineering fundamentals remain as crucial as ever, even as digital tools advance. Prof. Lariyah explored how digital platforms, artificial intelligence and risk-based frameworks are shaping the next generation of dam safety practice. She emphasised the importance of the human layer: building institutional readiness, strengthening safety culture, fostering stakeholder trust, and ensuring effective engagement with communities.

Together, their perspectives reinforced that the future of dam safety will depend on both technological innovation and human-centred capability and how effectively these dimensions interact. That’s something Entura is focused on as we continue to bring deep expertise and experience, while exploring and testing the possibilities of new technology to support design and analysis.

Learning from incidents to strengthen global knowledge

Another highlight for me was chairing a session on dam surveillance, monitoring and evaluation. Seven presentations, while different in context and purpose, in combination emphasised the power of data and the importance of learning from experience.

A standout paper examined the 2022 landslide incident at Kenyir Dam, an event that occurred quite soon after Entura’s dam safety inspector training program used the dam as a site visit capstone. Despite extreme rainfall and slope instability, and some damage to appurtenant structures and spillway, instrumentation data confirmed that the dam behaved as designed. What was also clear was that, largely, the instrumentation in place and the data that was able to be collected was a positive demonstration of the importance of robust dam design and monitoring systems.

Another paper explored machine-learning approaches to forecasting short-term reservoir levels at Batang Ai Hydroelectric Project – a scheme with which Entura has long been associated. The results were impressive and point to a future where AI-supported forecasting strengthens real-time operations, especially under increasing climate variability.

These are exactly the kinds of insights our industry must continue to share openly and widely. We can never ‘design out’ all risk, but we can reduce it through good data and continual reflection and learning from real-world events.

Strengthening long-term capability in Malaysia

ICDSME2025 also highlighted the importance of building capability – something I am passionate about. It was encouraging to see Malaysia’s Certified Dam Safety Inspector program, developed with input from Entura’s training arm ECEWI, growing into a sustained and locally led pathway, launched during the conference. Strengthening dam safety ultimately depends on skilled people and strong institutions, making investment in training an investment in long-term sustainability of dam safety governance – and ultimately greater national resilience. We hope to continue to work with MYCOLD to determine how our specialised expertise can further enhance capability uplift beyond surveillance, extending to dam safety risk decision making and dam safety engineering.

A shared commitment to the future

Conferences like ICDSME2025 are timely reminders of our collective responsibility and the shared purpose we need to bring to the challenges ahead. We’re all navigating the same landscape, and when we come together – sharing data, stories and lessons – we accelerate progress for everyone.

I am grateful to MYCOLD for the invitation to contribute and for the generous knowledge-sharing throughout the event. I left Sarawak optimistic: the connection, commitment and collaboration across our sector have never been stronger as we work toward our common goal: safer, more sustainable dams and hydropower systems that support resilient futures.

FIND OUT MORE ABOUT AMANDA

Can you trust advanced tools without qualified professionals behind them?

To make confident decisions about renewable energy assets – from building a wind farm to monitoring dam performance or optimising asset management – owners and operators need precision data they can trust.

As the renewable energy sector becomes increasingly digitised, the quality of measurements matters more than ever. Digital twins, predictive analytics, AI-driven performance tools and remote operations all depend on reliable, precise and traceable data.

Good data provides visibility. It lets owners and operators detect faults or safety issues early, optimise performance, and protect reliability and revenue. For example, accurate turbine alignment during installation or refurbishment could save hundreds of thousands of dollars in downtime and maintenance.

However, data only provides value if it has the right level of accuracy for the job intended. If the data isn’t up to scratch, the decisions won’t be either.

Keeping pace with technology is a steep learning curve

Surveying has always been the backbone of infrastructure development, land management and industrial precision. From the early days of using theodolites and chains to today’s cutting-edge technologies like laser scanning, UAV photogrammetry and LiDAR, the discipline has evolved dramatically. Yet, one constant remains: the need for appropriately qualified and experienced professionals.

Surveying is far more than measuring distances – and achieving precision requires more than sophisticated instruments. It requires a deep understanding of geodesy, data integrity, error propagation and spatial analysis. Traditional instruments such as theodolites and total stations demand mastery of angular measurement and trigonometric principles. GNSS-based methods introduce complexities like satellite geometry, atmospheric corrections and datum transformations. As technology advances, the learning curve steepens: laser scanners and UAVs generate massive point clouds, while LiDAR systems demand expertise in filtering, classification and 3D modelling.

Surveying principles now extend beyond land and construction into industrial metrology, where precision is measured in microns rather than millimetres. In the renewable energy sector, the applications are vast, from assessing hydropower turbine blade wear and integrity of concrete structures to verifying the verticality of wind turbines and ensuring accurate positioning of new hydraulic equipment. Here, advanced techniques like laser trackers and terrestrial laser scanning dominate, and the margin for error is extremely small.

Precision gives confidence that the data feeding an asset’s digital models is accurate, consistent and aligned with recognised standards. When survey instruments, operational sensors and digital monitoring systems all work within a strong metrological framework, asset owners can be confident that their decisions are based on fact, not noise.

The human behind the technology

However sophisticated today’s measurement tools and technologies may be, their outputs are only as trustworthy as the professionals behind them.

Without properly qualified and experienced operators, advanced tools can become liabilities rather than assets. Misinterpretation of data or incorrect calibration can lead to costly errors in construction, infrastructure alignment or asset management.

Using the wrong technique or sensor for the use case and conditions, neglecting appropriate calibration, and a lack of adequate redundancy can lead to major issues and costly mistakes.

Specialised, qualified professionals will think through these issues early, ensuring that accuracy and tolerance requirements are clearly defined from the start and that data integrity is maintained throughout with robust quality control and assurance procedures.

Human insight provides the environmental and engineering context and assurance that automated systems alone cannot deliver. Surveying and metrology professionals can determine whether readings are valid and offsets are accounted for – and will be able to distinguish genuine change from measurement anomalies.

Ultimately, it is professional judgement that transforms accurate data into actionable insights and confident decisions.

Accuracy drives advantage

Today’s surveying advances are transforming how decisions are made. Spatial data is no longer just a technical input; when validated and interpreted by qualified professionals, it becomes a valuable source of real strategic insight and advantage. When the data is right from the start, every subsequent step becomes more certain and the outcomes have the best chance of being more efficient and sustainable. Such clarity can be the difference between success throughout an asset’s lifecycle and expensive lessons learned.

As technologies advance, so does the need for qualified professionals who understand both the science of measurement and the realities of complex, dynamic infrastructure. By ensuring accuracy, compliance with standards and efficient workflows, the qualified surveyor safeguards projects from financial and reputational risks – enabling the reliability, safety and commercial confidence that every asset owner depends on.

If you’d like to talk to us about the potential of advanced surveying and metrology on your project, contact Phillip Ellerton or a member of our Spatial & Data Services Team.

Unlocking repowering for Australia’s older wind farms

Europe and the US are already upgrading older wind farms with powerful new turbines. Repowering could potentially offer significant opportunities in Australia’s energy transition, but there are barriers. Australia risks falling behind unless action is taken now to make repowering easier, faster and more attractive for investors. Dr Andrew Wright, Bunfu Yu and Donald Vaughan explore the opportunities for intervention …

To accelerate the clean energy transition, repowering old wind farms should be a serious consideration. Many of Australia’s earliest wind farms are reaching the middle or end of their design lives. These projects were pioneering at the time, but today’s turbines are taller, more efficient and capable of generating far more electricity from the same site – which is likely to have some of Australia’s strongest and most consistent wind.

Repowering could potentially offer a faster, cheaper and less disruptive way to boost renewable generation than building entirely new projects. Yet, despite the clear potential, repowering is still rare in Australia.

The pending closure of Pacific Blue’s Codrington Wind Farm in Victoria announced in February 2025 is an interesting case study, demonstrating potential barriers. Pacific Blue has concluded that a project with new wind turbines at Codrington is not financially viable once the existing turbines reach the end of their useful life. Consisting of 14 x 1.3 MW wind turbines and completed in June 2001, Codrington is one of the earliest wind farms completed in Australia. The site no doubt has a great wind resource, but its small size and the limited capacity of the 66 kV grid connection do not suit modern wind turbines, which are typically at least 4 times the size and capacity.  

Codrington is the largest old wind farm to announce its decommissioning in Australia. But other large early projects of similar age are also facing decisions about repowering or decommissioning.

This raises a question: are government and regulatory authorities properly prepared for an influx of ‘new old’ projects?

There is an expectation that larger wind farms will repower with new wind turbines, using and perhaps augmenting existing grid connections, under new development permits. But this concept is yet to be tested and proven in Australia.

How should governments and regulatory authorities in Australia deal with the planning approval aspects of repowering wind farms? Presently, they are considered like any other new development – but other countries have shown that repowering can be unlocked with practical mechanisms to incentivise developers, streamline planning and ease grid connection hurdles.

Incentivising repowering

Repowering requires significant capital investment – so a targeted financial incentive could make a meaningful difference in getting the project to stack up.

In Europe, there is a growing view that governments are not doing enough to drive forward the repowering of older wind farms that might otherwise carry on operating with inefficient use of land and resources. Local communities are typically comfortable living in the vicinity of wind farms that have been operating for a long period, so there is a strong argument that governments should develop specific policies to encourage repowering of old sites that already have community acceptance.

Germany led the way in direct policy intervention with a ‘repowering bonus’ included in 2009 in its Renewable Energy Sources Act, rewarding wind farm owners with a EUR 0.5 cent/kWh feed-in tariff bonus for replacing older wind turbines with modern, higher-capacity machines. This policy delivered more energy from fewer turbines while reducing land-use impacts. Repowering has subsequently become a significant contributor to Germany’s wind energy growth, with 1.1 GW of new wind capacity in 2023 coming from repowering.

In the USA, the Production Tax Credit (PTC) is now phasing out. This is an example of a policy that encouraged repowering as an unintended consequence. Enacted in 1992, it provided businesses with a tax credit per MWh of electricity generation for the first 10 years of a wind farm’s life. This created an incentive to generate as much output as possible for 10 years, and then build a new project to renew the tax credit. Given that 10 years is too short a lifetime for a well-engineered and well-run wind farm, this is not an ideal example of incentivising repowering.

Australia has no equivalent incentive for repowering. Early wind farms like Challicum Hills in Victoria, Starfish Hill in South Australia, and Tasmania’s Woolnorth wind farms are now approaching the end of their operating lives. Direct financial incentives or market mechanisms rewarding greater efficiency, reliability and grid services provided by repowered assets could make the difference between decommissioning these assets or repowering with new wind turbines to deliver decades more renewable energy.

Navigating approvals

In most cases, repowering will require additional planning and environmental approvals. This depends on the scale of the changes: are the turbines taller? are there new civil works? is the layout shifting? what new accesses or grid connection corridors might be required? The success of repowering depends on navigating approvals with the same care and thoroughness as for new projects.

Policy positions and guidelines have evolved over the last 2 decades, and there are now more stringent guidelines dictating the matters for consideration during approvals. Additional threatened or endangered species may also have been listed over the years.

Community engagement is a critical part of repowering and should not be overlooked. Even where communities have co-existed with a wind farm for decades, taller turbines or different layouts could raise new concerns about landscape impacts or amenity. Early dialogue and transparent benefit-sharing will help build trust and engagement in the project.

Clear planning, targeted environmental studies, and early engagement with regulators and communities can help projects capture the benefits of modern technology while minimising risks of delay.

A dedicated fast-track pathway for repowering would help these projects progress. Such a pathway could recognise prior approvals, with updates only where impacts materially change (e.g. taller turbine heights, new technology, and the cumulative effects of other developments), or where environmental values have changed. This doesn’t mean bypassing safeguards or consultation, but it does mean matching the level of scrutiny to the level of risk.

Easing grid connection challenges

Connecting a repowered project to the grid inevitably involves meeting stricter requirements than the original project, which will take time and add cost. Yet there is a strong argument that repowered projects should have some special considerations, given the differences between a greenfield development plugging into an existing network, and a replacement of an existing project with newer technology.

Proponents are faced with three paths: a new connection to the current rules, a grandfathered connection under the previous rules, or a hybrid approach. All of these have benefits and drawbacks. The best path will depend on the like-for-likeness of the repowering in terms of size, turbine technology and the amount of reused equipment (transformers and other electrical balance of plant).

Another consideration is whether the non-scheduled status of early wind farms can be preserved through this process. It is likely that significant changes to power or energy output may trigger a change. As a minimum, model accuracy requirements will apply to a new connection – which may lead to more detailed testing than the plant had previously been subjected to.

Options to help alleviate these challenges could include tailored connection pathways that recognise existing infrastructure, de-coupling from grid queue management for repowering projects, and clear technical standards so developers know what to expect.

As well as accelerating repowering, this could help make better use of grid assets, reducing pressure for new transmission.

What now for repowering?

Jurisdictions in Europe and the USA demonstrate that repowering works when governments set the right conditions. Early Australian projects such as Codrington, Starfish Hill, Challicum Hills and Woolnorth wind farms show that the time to decide is already here.

Given the challenges to achieve timely and cost-effective repowering in Australia, should we leave the low-hanging fruit of legacy sites dormant for now, and keep deploying capital on scale-efficient large sites in the short term?

Prioritising efficient large sites makes sense for urgent growth, but there are ways to pursue both greenfield and repowering – and the advantages of repowering remain. The early wind farms were built in some of the windiest, most accessible locations in Australia. Leaving these sites dormant would waste high-quality wind assets where there may already be community goodwill and existing grid assets.

Now is the time to consider whether particular site design approaches could make a site more easily repowerable in future – such as the way reticulation is installed, different approaches to foundations, scalable switchrooms and yard layouts. Is there a niche for wind turbine OEMs to offer lower power variants of new designs to better suit the scale of repower sites? Creativity and innovation will be needed – because the transition is too big and too urgent for us to leave repowering in the ‘too hard’ basket.

By pursuing both new developments and repowering simultaneously, Australia could capture immediate growth from large-scale projects while also making efficient use of our best wind resources and existing assets, maintaining community benefits and regional employment, and avoiding a wave of retired or stranded capacity.

If you are considering your wind farm’s future options and opportunities, please contact Andrew Wright or Patrick Pease.

ABOUT THE AUTHORS

Dr Andrew Wright is Entura’s Senior Principal, Renewables and Energy Storage. He has more than 20 years of experience in the renewable energy sector spanning resource assessment, site identification, equipment selection (wind and solar), development of technical documentation and contractual agreements, operational assessments and Owner’s/Lender’s Engineer services. Andrew has worked closely with Entura’s key clients and wind farm operators on operational projects, including analysing wind turbine performance data to identify reasons for wind farm underperformance and for estimates of long-term energy output. He has an in-depth understanding of the energy industry in Australia, while his international consulting experience includes New Zealand, China, India, Bhutan, Sri Lanka, the Philippines and Micronesia.

Bunfu Yu is a dynamic young leader in renewable energy planning, approvals, and business development. Bunfu played a pivotal role in Entura’s Environment and Planning Team’s success in achieving the Planning Institute of Australia’s National Award for Stakeholder Engagement in 2024. In 2023, Bunfu was named the National Young Planner of the Year by the Planning Institute of Australia. This honour recognised not only her passion for the planning and delivery of renewable infrastructure but also her active contribution to the profession through mentoring, public engagement, and knowledge sharing. She is currently a Senior Environmental Planner and a Business Development Manager at Entura.

Donald Vaughan has over 20 years’ experience providing advice on regulatory and technical requirements for generators, substations and transmission systems. He has worked for all areas of the electrical industry, including generators, equipment suppliers, customers, NSPs and market operators. Donald specialises in the performance of power systems. His experience in generating units, governors and excitation systems provides a helpful perspective on how the physical electrical network behaves.

From feasibility to operations: how technical due diligence can empower renewable energy investment

Confident investment in renewable energy projects is the key to accelerating the clean energy transition. Yet every renewable energy project carries some uncertainties at every stage, from early feasibility to long-term operations.

For all involved – developers and contractors, investors and lenders, stakeholders and communities – trust in a project’s viability and success will grow when there is a strong framework in place to thoroughly assess and quantify the project’s technical and financial assumptions, risks and unknowns.

Robust technical due diligence needs to span all the stages of the project’s development, though its focus will change as the project evolves.

Here we examine how sound technical due diligence, applied throughout the lifecycle of a renewable energy project, can provide a strong foundation for sustainable delivery and greater confidence of a bankable investment.

Due diligence is an ongoing process

Technical due diligence of renewable energy projects (including wind, solar or hydropower) isn’t a one-off activity. It evolves as a project advances.

The aim in the early stage is to verify the design assumptions and to determine if a concept can evolve into a viable investment.

During execution (construction), the emphasis shifts to project monitoring and adaptive risk management, ensuring that construction progress aligns with budgeted milestones.

Once operational, the focus is on assessing the project’s outputs (energy generation, efficiency, etc.) and maintenance practices while also ensuring contractual integrity, which is critical for refinancing or acquisition decisions.

Together, these different phases of due diligence form a continuum of technical supervision which ultimately helps to support the long-term success of the project.

Pre-construction phase

Pre-construction due diligence is a multidisciplinary process that assesses site conditions, verifies design feasibility, and validates operational feasibility. This leads to more realistic financial projections, which in turn enable objective and systematic investment decisions.

Key elements of pre-construction due diligence typically include review or assessment of the following:

Execution phase (construction)

Once a project secures financing and enters the construction phase, the technical due diligence focus moves to active oversight of whether the project is being delivered safely, efficiently and to the required standard. The consultant helps the project achieve timely outcomes during construction and commissioning. The key elements of technical supervision during construction include the following:

These assessments help to identify deviations from plans, enhance transparency and reinforce investor confidence.

Operational phase (existing assets)

For businesses considering investing in or acquiring operational assets, due diligence helps to assess how the asset is performing, verify the asset’s physical condition, and identify improvements that can sustain value into the future. This is essential for establishing accurate valuations and identifying hidden risks. A competent technical consultant can offer tailored services that combine desktop reviews with on-site inspections to inform the investment decision.

Key components of due diligence of existing assets include the following:

This stage of due diligence is especially relevant in a secondary market, where investors are seeking to invest in brownfield assets to diversify their portfolios. The goal is to ensure that the asset’s operational reality matches its financial promise.

Building confidence from concept to operation

Entura has seen firsthand how due diligence strengthens projects at every stage. We’ve fulfilled many technical due diligence and advisory roles in different contexts – and sometimes multiple roles on a single project.

For continuity, a single consultancy can take on a range of responsibilities across the different phases of a project: whether that’s technical feasibility assessment, technical due diligence, Owner’s or Lender’s Engineer roles, or Independent Technical Advisor. These roles are different in focus, timing and perspective, but they’re ultimately all about building confidence in the viability and success of the project.

One example is the Kidston Pumped Storage Project (K2-Hydro), for which Entura initially prepared the technical feasibility assessment considering factors that influence the project’s technical and commercial viability, and then played an advisory role leading to financial close. During the construction phase, our role shifted to that of Owner’s Engineer, helping to ensure the project’s designs meet current practice and that construction is implemented in accordance with the designs and specifications.

In the pre-construction stage, Entura has completed technical due diligence of many hydropower and other renewable energy projects. For example, we’ve recently taken on this role for several hydropower projects planned for development in India, ranging from a 32 MW hydropower project right through to an 1800 MW pumped storage project. These assessments included hydrological studies, power potential studies and reviews of project layout, plant design and electro-mechanical works, power evacuation arrangements, power purchase agreements, technical risks, costs and construction schedule, and more.

We’ve also conducted due diligence for many solar, wind and hybrid renewable energy projects. For example, Entura was engaged as the technical due diligence consultant for the 112 MW Granville Harbour Wind Farm to support the client’s financial closure. We provided technical services including energy estimates, review of permits and grid connection, development of technical specifications, review of the project design, and checks of environmental compliance– all necessary for successful financial closure.

We continued our involvement into the construction stage as Owner’s Engineer, providing construction support, overseeing the civil and geotechnical components of construction, and conducting regular site inspections to ensure the works were undertaken in accordance with the relevant industry and safety standards.

Translating technical findings into financial indicators

Technical due diligence at every stage of a project’s lifecycle requires a level of rigour that goes beyond a simple compliance requirement. It is fundamental to long-term asset performance, stakeholder trust and the validity of financial assumptions and projections. Consultants involved through the feasibility, construction and operational phases can contribute meaningfully to the project development.

Although financial modelling lies outside a technical consultant’s scope, their work forms the backbone for credible financial analysis and investment decisions that are integral to the overall business case development. Each finding from the technical process can be used to support further financial due diligence to inform investment, lending or acquisition decisions.

By structuring the technical findings around the following four financial pillars, technical due diligence becomes a bridge between the on-the-ground realities of the project and its ultimate financial viability.

What does this mean for stakeholders?

Sound technical due diligence can cater to the financial expectations of different stakeholders making it a key instrument for strategic decision support.

• Long-term investors (developers or buyers) prioritise clarity on returns, dividend sustainability, and resilience of the asset into the future. Their confidence hinges on realistic operation plans, reliable energy forecasts, and durable O&M strategies derived from feasibility assessments and construction-phase monitoring.
• Debt providers focus on debt-service coverage ratios (DSCR) which indicate the capacity of the project to generate sufficient revenue to repay loans. Lenders will want reassurance about budget contingencies, capability of contractors and robustness of project schedules – all of which are assessed in detail during the due diligence.
• Insurers require information about structural failure modes, the risks of operational outage, and force-majeure conditions. These can be informed by detailed technical analyses and condition assessments from operational audits.

When applied consistently throughout the course of a project, from feasibility to operations, technical due diligence helps all stakeholders measure project risks, avoid unexpected costs, and evaluate potential and actual performance. This is the bedrock for confident financial decisions – and ultimately, for driving the energy transition forward at the scale and pace our environment and communities urgently need.

ABOUT THE AUTHOR

Sagar Shiwakoti is a civil engineer with master’s degree in water resources engineering and close to a decade of experience in flood studies (hydrological and hydraulic assessment) and hydraulic design for hydropower projects. Prior to joining Entura in 2022, he worked with the Nepal Electricity Authority and Hydroelectricity Investment and Development Company, where he gained extensive experience in technical due diligence for hydropower projects. Sagar was also a lecturer in civil engineering for a number of years at Tribhuvan University, Kathmandu.

New technologies give deeper insight to protect the shallows

Water is a precious resource for communities and industries – and for the health of river ecosystems. Balancing these needs around dams can be very complex. In this article, Dr Will Elvey and Dr Colin Terry explore how advanced technologies and methods can help dam owners/operators better understand shallow downstream areas to support aquatic biodiversity …

Dams are crucial for many communities, providing water security, energy and economic growth – but they also change the natural flow of rivers and streams.

To preserve downstream ecosystems and species, ‘environmental flows’ (e-flows) began to be implemented in hydropower operations from the 1970s and the concept became more sophisticated and more formalised as the decades rolled on. In Australia, e-flow assessments are now typically required by state or Commonwealth regulators for new dam projects or major operational changes.

These assessments are complex and challenging both for new developments and for retrofitting existing schemes. As the concept of e-flows continues to evolve, methods of modelling and assessing these flows must evolve too.

Getting a deeper understanding of what’s downstream

Scientific understanding of the ecological requirements of freshwater species and the physical processes that shape their habitats has advanced significantly since e-flow studies began. Many aquatic species exhibit preferences, or even strict dependencies, on specific velocities and depths. To accommodate those preferences or dependencies, it’s vital to better understand how habitat availability and quality respond to different e-flow regimes (i.e. the timing of discharge and the diversity of velocity and depth across the channel).

There are many approaches for simulating habitat changes under varying flow conditions, but all rely on hydraulic models. E-flow assessments are often constrained by the capabilities of the hydraulic models used, and simpler models are generally inadequate for addressing complex ecological questions. Attempts to use simple models to inform more detailed ecological metrics, such as habitat preference curves for individual species, often fail to deliver the intended environmental outcomes.

Using simple models can lead to adopting basic flow rules, where benefits are difficult to quantify beyond broad estimates (e.g. maintaining wetted channel widths or meeting minimum depth thresholds). The inherent limitations of simplistic hydraulic modelling can also make it difficult to justify proposed environmental water releases to regulatory agencies and water resource managers.

Simple models suit simple questions only

Early environmental flow studies commonly used one-dimensional (1D) hydraulic models, which assume uniform water properties across the channel and throughout the water column, varying only along the main flow direction. But in reality, the shape of a watercourse and its hydraulic properties are too variable to be able to be simulated well by 1D models.

Shallow water zones in rocky riverbeds – which are often highly ecologically diverse and are vulnerable in droughts or insufficient flows – are particularly hydraulically complex.

1D models are still used and do provide useful general information such as wetted cross-sectional area, average velocity, and minimum and maximum depths. However, they lack detail about vertical and lateral flow dynamics and can’t simulate water movement around complex in-channel structures like rock substrates or little waterfalls.

This means that 1D models are best suited to answering relatively simple questions – for example, how different discharge changes the wetted area, or what the maximum and minimum depths and velocities are for a cross-section.

1D models, when configured with sufficient cross-sections through complex areas of riverbed, can more effectively address questions such as whether minimum depths allow fish to pass through shallow reaches during low flows, or whether velocities are sufficient to support macroinvertebrates that thrive in faster flowing areas, such as stoneflies, mayflies, caddisflies, elmid beetles and some dragonfly species.

Estimating water velocity is crucial for understanding how physical habitat is maintained through the mobilisation of bed particles, from the fine silts to the largest rocks.

The accumulation of fine sediments on surfaces, and within the spaces between and beneath rocks, can degrade habitat quality for many aquatic species. Simulations of water velocity and associated shear stress can help determine whether flows are sufficient to transport fine sediments away from riffle habitats.

At the other end of the spectrum, annual peak flows of sufficient magnitude to mobilise larger substrate classes (from gravels to boulders) play a key role in maintaining healthy river systems. However, the low spatial resolution and limited physics of 1D models means they can only contribute to general estimates of bed mobilisation.

New technologies reveal more detail – informing better e-flows

Emerging field observation methods and computer modelling approaches that are more sophisticated and detailed can better guide environmental releases, particularly where the riverbed slope and substrate vary. These environments require a deeper understanding of the dynamics of shallow flow to support ecologically meaningful outcomes.

In the past, field measurement was limited to point surveys at cross-sections, and computers only had the capacity for modelling 1D versions. Now, with accurate airborne drone surveys using photogrammetry and LiDAR, scientists can better describe the physical geometry of a watercourse.

Advanced computer hardware and 3D modelling software are enabling a more accurate – and more rapid – understanding of water behaviour. It is now possible to create a plausible 3D time-varying version of the water flow, with detail that enables aquatic scientists to provide better advice on appropriate environmental flows. Fewer limitations generally leads to more cost-effective insights and, in turn, better management of environmental values.

Modern methods in practice

This example demonstrates the power of evolved methods and new technologies.

A 600 m stretch of a river that is approximately 20 m wide, with a rocky bed, was surveyed by drone, capturing 1,260 images which were used to create a highly detailed 3D version of the river’s geometry. Then, using 2D and 3D hydraulic software, different flows in the test area were simulated, ranging from a trickle to larger floods. The critical flows for healthy aquatic life are the diverse shallow flows in areas large enough to allow an abundance of diverse life.

Figure 1 gives a typical view of the river. Figure 2 shows samples of the geometry captured and processed. Figure 3 shows output from the 3D hydraulic modelling software.

Figure 1. River at low-flow gauging (0.0077 m³/s) site looking upstream and downstream

Figure 2.  a) Aerial image, b) DTM, c) 2D grid, for the same area of river

Figure 3. Water surface with scaled velocity vectors, looking upstream for 3 m³/s (3D model)

ABOUT THE AUTHORS

Dr Will Elvey is a Senior Environmental Scientist with Entura specialising in aquatic invertebrates, freshwater fish, freshwater habitats and ecohydrology. Will has nearly three decades of experience as a consultant in Tasmania and the United Kingdom. He has been involved in a wide range of projects that include assessing impacts of stressors on aquatic ecosystems.

Dr Colin Terry is Entura’s Senior Principal, Water (Hydraulics/Hydrology). Colin has over three decades of engineering experience, most with a water focus. He has expertise in water modelling, design and planning of dams, hydropower and water infrastructure, including 3D CFD analysis of hydropower intakes, rivers and dam spillways. Colin has worked at senior technical levels of small and large organisations across Australia and New Zealand.

‘Dams for People, Water, Environment and Development’ – some reflections from ICOLD 2024

Entura’s Amanda Ashworth (Managing Director) and Richard Herweynen (Technical Director, Water) recently attended the International Commission on Large Dams (ICOLD) 2024 Annual Meeting and International Symposium, held in New Delhi. Amanda presented on building dam safety capability, skills and competencies, while Richard presented on Hydro Tasmania’s risk-based, systems approach to dam safety management, and the importance of pumped hydro in Australia’s energy transition. 

Here they share some reflections on ICOLD 2024 …

Richard Herweynen – on the value of storage, ‘right dams’, and stewardship

At ICOLD 2024 we were reminded again that water storages will be critical for the world’s ability to deal with climate change and meet the growing global population’s needs for food and water. We can expect greater climate variability and therefore more variability in river flows, which means that more storage will be needed to ensure a high level of reliability of water supply. Without more water storages to buffer climate impacts, heavily water-dependent sectors like agriculture will be impacted.

To slow the rate of climate change, we must decarbonise our economies – but without significant energy storage, it will be difficult to transition from thermal power to variable renewable energy (wind and solar). Pablo Valverde, representing the International Hydropower Association (IHA), said at the conference that ‘storage is the hidden crisis within the crisis’. There was a lot of discussion at ICOLD 2024 about pumped hydro energy storage as a promising part of the solution. It is also important, however, to remember that conventional hydropower, with significant water storage, can be repurposed operationally to provide a firming role too. Water storage is the biggest ‘battery’ of the world and will be a critical element in the energy transition.

With the title of the ICOLD Symposium being ‘Dams for People, Water, Environment and Development’, I reflected again on the need for ‘right dams’ rather than ‘no dams’. ‘Right dams’ are those that achieve a balance among people, water, environment and development. In the opening address, we were reminded of the links between ‘ecology’ and ‘economy’ – which are not only connected by their linguistic roots but also by the dependence of any successful economy on the natural environment. It is our ethical responsibility to manage the environment with care.

When planning and designing water storages, we must recognise that a river provides ecological services and that affected people should be engaged and involved in achieving the right balance. If appropriate project sites are selected and designs strive to mitigate impacts, it is possible for a dam project’s positive contribution to be greater than its environmental impact, as was showcased in number of projects presented at the ICOLD gathering. Finding the balance is our challenge as dam engineers.

The president of ICOLD, Michel Lino, reminded delegates that the safety of dams has always been ICOLD’s focus, and that there is more to be done to improve dam safety around the world. At one session, Piotr Sliwinski discussed the Topola Dam in Poland, which failed during recent floods due to overtopping of the emergency spillway. Sharing and learning together from such experiences is an important benefit of participating in the ICOLD community.

Alejandro Pujol from Argentina, who chaired one of the ‘Dam Safety Management and Engineering’ sessions, reflected that in ICOLD’s early years the focus was on better ways to design and construct new dams, but the spotlight has now shifted to the long-term health of existing dams. It is critical that dams remain safe throughout the challenges that nature delivers, from floods to earthquakes. In reality, dams usually continue to operate long beyond their 80–100 year design life if they are structurally safe, as evidenced in the examples of long-lived dams presented by Martin Wieland from Switzerland. He suggested that the lifespan of well-designed, well-constructed, well-maintained and well-operated dams can even exceed 200 years. As dam engineers, no matter the part we play in the life of a dam, we have a responsibility to do it well.

From my conversations with a number of dam engineers representing the ICOLD Young Professional Forum (YPF), and seeing the progress of this body within the ICOLD community, I believe that the dam industry is in good hands – although, of course, there is always more to be done. I was pleased to see an Australian, Brandon Pearce, voted onto the ICOLD YPF Board.

Another YPF member, Sam Tudor from the UK, reminded us in his address of the importance of knowledge transfer, the moral obligation we all have especially to the downstream communities of our dams, and our stewardship role. He was referencing his experience of looking after dams that are more than 120 years old – all built long before he was born. Many of our colleagues across Entura and Hydro Tasmania feel this same sense of responsibility and pride when we work on Hydro Tasmania’s assets, which were built over more than a century and have been fundamental to shaping our state’s economy and delivering the quality of life we now enjoy. It is up to all of us to carry the positive legacy of these assets forward with care and custodianship, for the benefit of future generations.

Amanda Ashworth – on costs and benefits, dam safety, and an inclusive workforce

Like Richard, I found much food for thought at ICOLD 2024. For me, it reinforced the need to accelerate hydropower globally, particularly in places where the total resource is as yet underdeveloped. To do so, we will need regulatory frameworks that support success – such as by monetising storage and recognising it as an official use – and administrative reforms that ease the challenges of achieving planning approvals, grid connection agreements and financing for long-duration storage. We must encourage research and development to move our sector forward: from multi-energy hybrids to advanced construction materials and innovations to improve rehabilitation.

In particular, I’ve been reflecting on how our sector could extend our thinking and discourse about the impacts and benefits equation beyond the broad answer that dams are good for the net zero transition. How can we enact and communicate the many other potential local environmental and social benefits and long-term value from dams?

Much of the world’s existing critical infrastructure came at a significant financial expense as well as social and environmental costs – so it is our obligation to pay back that investment by maximising every dam’s effective life. When we invest in extending the lifespan of dam infrastructure through effective asset management and maintenance, and when we maximise generation or the value of storage in the market, we increase the ‘return on investment’ against the financial, social and environmental impacts incurred in the past.

Of course, the global dams community must continue to prioritise dam safety and work towards a ‘safety culture’. I was pleased to hear Debashree Mukherjee, Secretary of the Ministry of Jal Shakti, celebrate the progress on finalising regulations across states to enact India’s Federal Dam Safety Act and establishing two centres of excellence to lift capacity across the nation. Dam safety depends on well-trained people with the right skills and competencies to comply with evolving standards, apply new technologies, and respond effectively to changing operational circumstances and demands. 

I also enjoyed hearing from ICOLD’s gender and diversity committee on its progress, including updates from around 14 nations on their efforts to build a more inclusive renewable energy and dams workforce. This is front of mind for us, as we step up Entura’s own focus and actions on gender equity throughout our business this year.

The challenges facing our dams community – and our planet – are enormous, but there is certainly much to be excited about, and we look forward to continuing these important conversations over the next year.

From Richard, Amanda and Entura’s team, many thanks to the Indian National Committee on Large Dams (INCOLD) for organising and hosting this year’s ICOLD event, supporting our sector to build international professional networks, and facilitating the sharing of experiences and knowledge across the globe – all of which are so important for growing the ‘ICOLD family’ and supporting a safer, more resilient and more sustainable water and energy future.

Growing the future of hydropower – observations from a career in the industry

Entura’s Senior Principal Hydropower, Flavio Campos, knows hydropower inside out. Flavio has recently joined Entura, after working around the world on significant hydropower projects ranging from 30 MW to a whopping 8,240 MW. We asked him to share some of his hydropower journey, what excites him about the future of the sector, and what’s different about conventional hydropower and pumped hydro in supporting the clean energy transition …

When I immigrated from Brazil to Canada in 2012, it was no accident that I settled in Ontario, near Niagara Falls. I had taken a job with a consulting firm that had a hydropower hub strategically located in the Niagara region due to its long history of hydropower.

The Niagara region is the home of the Adams Power Plant, completed in 1886 – the first alternating current (AC) power plant built at scale, delivering an installed capacity of 37 MW at 2,200 V. The voltage is stepped up by a transformer to 11,000 V, allowing for an economic transmission line reaching to the city of Buffalo, NY, 32 km away. The concept was launched by engineer Nikola Tesla in collaboration with George Westinghouse, beating Thomas Edison’s bid, which was based on a direct current (DC) system. Tesla’s dream of harnessing the awesome power of Niagara Falls was realised by the end of the 19^th century, when hundreds of small hydropower plants emerged and multiple forms of electricity utilisation spread across the world.

The hydropower boom, led by Brazil and China

When I started my career in the hydropower industry in 1995, I could feel the ongoing impact of the great hydropower boom that was led by Brazil and China through the 1970s and 1980s. In 1999, I was construction manager for Tucurui Dam, one of the biggest hydropower plants in Brazil and the world at that time (now ranked 8^th in the world), delivering a total installed capacity of 8,240 MW. As part of my role, in order to raise production to the expected rates, I was able to visit China’s Three Gorges Dam during construction and learn about their techniques and massive concrete operations.

In the 1990s, Brazil’s hydropower industry had plenty of experienced professionals, from construction trading foremen and general superintendents to highly educated engineering professionals from whom I had the privilege to learn.

Since those glorious decades, global hydropower capacity has increased significantly. The strongest period was 2007 to 2016, when more than 30 GW was added per year on average. Since 2017, the industry has slumped to only 22 GW per year on average, with only 13.7 GW installed in 2023. However, it is interesting that of the new 13.7 GW, 6.5 GW was delivered as pumped hydro energy storage.

A new wave of pumped hydro

At a HydroVision International conference in Portland, Oregon, in 2019, I noticed that pumped hydro was a significant topic of discussion. The conference highlighted several factors making pumped hydro projects attractive for the clean energy transition: the ‘battery’ feature itself which helps to balance supply and demand, its contributions to grid stability, its lower environmental impact compared to conventional hydropower, the availability and efficiency of variable-speed units, and the cost comparison against other types of batteries.

Projections of a new wave of pumped storage soon evolved from conference coffee-break chatter to reality: in 2022, more than 10 GW of pumped hydro was delivered, the most ever achieved by the industry. Most of this has been delivered in China, where top-down policies imposed by government can deliver rapid results. Other countries operating on a more open-market basis need to improve the mechanisms to foster pumped hydro so that it can support the grid effectively as other variable renewable energy (VRE) sources, such as wind and solar, proliferate.

There is now consensus that pumped hydro is a necessity for grids to cope with increasing amounts of VRE– and the need is urgent. Pumped hydro, however, requires significant upfront investment in civil works and time to implement. Studies by the IHA indicate that besides the inherent need for additional pumped storage in the grid, the world’s conventional (non-pumped) hydropower installed capacity must double by 2050 in order to achieve net-zero transition targets. This will be challenging, given such a low level of new hydropower worldwide in recent years, and the fact that the most attractive sites have been already developed.

There is also opportunity to re-imagine existing conventional hydropower plants to make the most of their natural battery and firming potential – by operating flexibly to support firming VRE rather than generating for maximum volume. Even where there is no market mechanism to specifically monetise this value, it could be rewarded for national or regional outcomes.

How can we achieve the much-needed growth in conventional hydro and pumped hydro?

Conventional (non-pumped) hydropower has long been recognised for clean energy and the long life of the infrastructure. The challenge now is to identify, gain approvals and sustainably deliver new projects in a world where human occupation is growing fast and reaching into the most remote corners of watersheds. Governments and regulators must assess cost benefits against the social and environmental impacts before giving the green light to new hydropower projects.

Developing pumped hydro can be more flexible, especially when it is a closed-loop system that doesn’t depend on water flows, except for first-time filling and for topping up the losses caused by evaporation. Pumped hydro is not new – in fact, it has existed for more than a century. What is new, however, is the challenge of fostering pumped hydro development at the rate needed.

The IHA has helped clarify what is needed for the industry to develop pumped hydro faster. The IHA’s Guidance Note delivers recommendations to reduce risks and enhance certainty, supporting market players to better understand the issues.

Another interesting initiative in the hydropower journey is XFLEX Hydro, a European initiative which brought together 19 entities such as IHA, EDP, EDF, Alpiq, Bechtel and others, with the objective of increasing hydropower capabilities and flexibility to cope with changing grid profiles. X-Flex has launched 7 pilot projects already – and 4 of these are pumped hydro. This combined initiative has illustrated two important areas of focus that can benefit market players and accelerate uptake:

1. The need for a supportive regulatory regime: Policy-makers and other stakeholders need to facilitate the development of regulations or market mechanisms that fairly compensate pumped hydro, as well as conventional hydropower, such as ‘price cap and floor’ mechanisms, compensation for stability features provided by hydropower, and expediting the approval process while ensuring that social and environmental impacts are minimised and mitigated.
2. The advantages of evolving technologies, including:
   • variable-speed units, increasing flexibility
   • hydraulic short-circuit operation, in which the plant can pump and generate simultaneously
   • hydro/battery hybrid system, in which the battery works along with hydropower and enhances plant flexibility
   • digital/AI control platforms, which can improve the overall grid efficiency and reduce downtime.

Hydropower for a better future

The challenges of rapidly building out new conventional hydropower and pumped hydro are huge. Yet, where there is a will, there is a way. Those of us who understand and believe in the benefits of conventional hydropower and pumped hydro have a duty to bring communities along on the journey and to help build a better future for the next generations.

We look forward to bringing you more of Flavio’s insights into conventional hydropower and pumped hydro in future articles. Flavio is currently contributing to a number of Entura’s assignments including supervising construction on the Genex Kidston PHES project in Queensland, for which Entura is the Owner’s Engineer, and being a key adviser on the Tarraleah upgrade as part of Hydro Tasmania’s Battery of the Nation program.

Understanding the business risks of small dams and weirs

Small dams may pose significant business risks that are often under-appreciated, even if these dams don’t pose a safety risk to the community. Managing risk is a key part of running any sustainable business and understanding how to mitigate risks requires that they are properly identified, analysed and evaluated.

The Guidelines on Risk Assessment prepared by ANCOLD (Australian National Committee on Large Dams) provides a detailed process for quantitative analysis of dam safety risks for large high-consequence dams, but adopting this process for small dams and weirs can be costly and may not be clearly justifiable.

For owners of small dams, ANCOLD has a number of other guidelines that can be useful for managing these dams, including Guidelines on the Consequence Categories for Dams and Guidelines on Dam Safety Management. Assigning a consequence category for a small dam can be a useful first step in understanding the risks – and will consider the impacts on community safety, on the environment, on the dam owner’s business, and on other social factors including impacts on health, community and business dislocation, loss of employment and damage to recreational facilities and heritage.

The consequence categories are graded from ‘Low’ to ‘Extreme’. These categories are used for a number of purposes including:

• regulatory requirements (depending on which state the dam is in)
• recommended surveillance and monitoring activities
• maintenance and operational requirements
• spillway flood capacity
• dam design standards.

The focus of ANCOLD’s consequence category guidelines is on wider community safety and impacts, but not on the dam owner’s business. This potentially leaves the dam owner exposed to significant unidentified business risks. Ideally, these should be managed consistently alongside all the other business risks.

A structured approach to assessing the business risks of small dams

ANCOLD’s Guidelines on Risk Assessment is a useful starting point for undertaking a business-focused risk assessment of small dam assets. As with all risk assessments, it is useful to follow a structured approach, including the following steps:

1. identify the hazards
2. brainstorm the failure modes
3. estimate the likelihood of the failure
4. estimate the consequences of failure
5. evaluate the risks
6. develop risk mitigation measures.

Such a risk assessment approach is ideally completed with a dam engineer working closely with the business owner to capture both the dam engineering and the business-specific knowledge. 

1. Hazards

Dams need to be properly designed, constructed and maintained to continue to perform their function safely. It is essential to avoid becoming complacent. Floods are a significant hazard to all dams and cause around 50% of all failures in large, well-engineered embankment dams. Small dams are often constructed with no or minimal engineering input into the design or construction and as a result may have inherent defects that may not manifest themselves until years later.

Dams in general do not require a lot of maintenance; however, a lack of suitable maintenance can lead to failures. A key maintenance activity is management of vegetation so that trees do not establish themselves in the embankment. Tree roots can create leakage paths that could lead to piping or internal erosion, and ultimately to a failure.

2. Failure modes

A key part of the expertise of a dams engineer is understanding how different types of dams can fail, which is crucial for identifying potential failure modes. The ANCOLD guidelines on risk assessment recommend completing a site inspection of the dam to help identify the key ways in which the dam could fail. The inspection should be conducted with the dam owner to look for evidence of failure modes, such as:

• deformation or cracking, which may indicate issues with the stability of the dam
• wet areas or flows through the dam, which may indicate a piping failure
• spillways where the original crest is filled in or raised to increase storage in the reservoir, which can often be an area of concern
• erosion close to the dam from operation of the spillway, which could lead to undermining and instability of the dam wall.

Typically, failure modes are identified in a workshop setting and then prioritised by criticality. The full list of failure modes is then reduced to a shortlist of those that are most critical.

3. Likelihood of failure

ANCOLD’s Guidelines on Risk Assessment provides an approach that can be used for detailed quantitative risk assessments; however, such approaches require significant effort to apply and can be costly. For small dams, it can be more appropriate to use a risk matrix approach, similar to that outlined in the Australian standard AS ISO 31000 Risk Management.

Typically, most businesses have a standard risk assessment procedure that can be adapted to give a qualitative or semi-qualitative assessment of likelihood. An experienced dams engineer will be able to assign a likelihood for each of the credible failure modes based on engineering judgement and some simple calculations (e.g. using regional flood estimates and estimates of the spillway discharge capacity). Failure modes for dams that are well designed and constructed will often have a likelihood rating of ‘Rare’ or ‘Unlikely’. The likelihood may be higher for dams in poor condition or with identified deficiencies.

4. Consequences of failure

A business risk assessment focuses on the consequences to the business, rather than the wider community, if the small dam were to fail. This will be unique to each business and will need input from the owner. It can be assessed by working through a series of questions about the need for the dam and its purpose – for example:

• What is the water in the dam used for? Can the business function without the water or the storage space in the dam?
• Are there alternative sources for the water that can be quickly accessed, and will these be sufficient for normal operations or would it be necessary to reduce operation?
• Is there business infrastructure downstream of the dam, and could a failure of the dam cause failure of these assets (e.g. pumping stations, water treatment plants or other dams) that would impact business operations? Can the business operate without these assets?
• How will customers be affected and what are the reputational consequences of not being able to supply or only partially supply?
• What are the financial implications for the business, and is there insurance that would cover the cost of the event, including consequential losses?
• How long would it take to replace the dam (including refilling) and the other assets?

5. Evaluation of risks

Using the business’s standard risk assessment tool enables comparison of the small dam risks against other business risks on a consistent basis (e.g. safety risks to employees). The level of risk will indicate the urgency of addressing the risk. This process allows a clearly articulated justification to be presented to the business for putting in place any required mitigations. It also enables the owner to focus on the key business risks rather than become distracted by issues with lower risk.

6. Risk mitigation

Mitigations can address either likelihood or consequences and will need to be tailored to the specific risks and the business needs. Addressing the risks by reducing the likelihood will typically involve physical works to the dam – for example, increasing the size of the spillway to reduce the likelihood of an overtopping failure, or managing vegetation to reduce the likelihood of a piping failure.

Where reducing the likelihood is not practical or not sufficient, addressing the consequences may be an effective approach. Addressing the consequences may involve options such as securing alternative water supplies, contingency planning to reduce impacts on customers, or insurance to cover the financial losses.

Bringing it all together for better business insights

Entura has undertaken qualitative and semi-qualitative small dam risk assessments for a number of clients in a cooperative environment to bring together our dams engineering expertise with the owner’s knowledge of their business. This is a cost-effective approach that has provided clarity on the specific business risks related to small dams, allowing targeted risk mitigation measures to be put in place. The process has provided important insights enabling owners to justify business decisions and reduce their overall business risk exposure.

If you have small dams and would like to talk with us about assessing your business risks, contact Phillip Ellerton or Richard Herweynen.

About the author

Paul Southcott is Entura’s Senior Principal – Dams and Headworks. Paul has an outstanding depth of knowledge and skill developed over more than 3 decades in the fields of civil and dam engineering. He is a highly respected dams specialist and was recognised as Tasmania’s Professional Engineer of the Year in Engineers Australia’s 2021 Engineering Excellence Awards. Paul has contributed to many major dam and hydropower projects in Australia and abroad, including Tasmania’s ‘Battery of the Nation’, the Tarraleah hydropower scheme, Snowy Hydro, and numerous programs of work for water utilities including SeqWater, Sun Water and SAWater. His expertise is a crucial part of Entura’s ongoing support for upgrade and safety works for Hydro Tasmania’s and TasWater’s extensive dams portfolios. Paul is passionate about furthering the engineering profession through knowledge sharing, and has supported many young and emerging engineers through training and mentoring.

The life cycle of a dam – Bringing it all together

Dams, like all of us, go through several life stages. Some dams have harder lives. Some age more quickly. Some need a lot of attention, and some are more robust. Let’s talk a bit about a dam’s life – and revisit some of our previous articles on dam engineering.

Phase 1: Inception

The starting point of the dam life cycle is the planning process – where a need is identified and it is determined that the way to meet that need is to create a water storage by constructing a dam. It is essential that this planning process involves effective stakeholder engagement. Although there may be a primary purpose for the dam, it is very common through the stakeholder engagement process to consider other benefits that the dam could provide, making it a multipurpose dam.

The planning process will lead to the site selection stage. Choosing a suitable site which is both technically sound and environmentally and socially acceptable will have a significant impact on the remaining stages of the dam’s life. Multi-criteria assessment can help get the selection right, ensuring technical, financial, environmental and social aspects are considered in a balanced way.

Read our articles:

• ‘No dams’ or ‘right dams’? That is the question
• Make better decisions about hydropower and dam project options using risk-based multi-criteria assessment

Phase 2: Development

The development phase includes the investigation, design and construction of the dam. Every dam site is different, and it is important to understand this. As a result, the ideal dam type for one location will not be the same as for another location.

Read our article:

• What is the best dam type for my dam site?

It is important that the risks associated with the dam site are known and understood. A key risk is the geological aspects of the dam’s foundation. Are there defects that could impact the stability of the dam? Are the foundations erodible? Could permeability be an issue? A staged investigation program formulated around the geological model will help to provide this understanding.

Read our article:

• Five steps to better understanding geological risks in hydropower projects

Design must be in accordance with current practice, guided by engineering standards and guidelines such as ANCOLD guidelines and ICOLD bulletins. Construction needs to be in accordance with the design and should be conducted using an appropriate quality assurance system and quality control program. An Independent Technical Review Panel (ITRP) helps avoid anything falling through the cracks. (The Queensland Dam Safety Management Guideline provides some guidance about this.) An ITRP will provide strong technical governance during design and construction, utilising the collective knowledge and experience of its members.

Read our article:

• Size isn’t everything when it comes to dam risks: A ten-point plan for safer dams

Phase 3: First filling

The next phase of the dam’s life is the first filling. This is a very exciting time, but it is also known to be the highest risk stage of a dam’s life. As a result, we need to be prepared. A dam safety system needs to be in place, along with the necessary instrumentation to monitor the dam during this first fill.

Read our article:

• Is your dam instrumentation telling you what you need to know?

In case of any incident occurring during first filling, it’s crucial that the dam safety emergency plan has been prepared and the dam safety manager identified. As the dam fills, there should be a heightened level of monitoring and surveillance, using this information to compare the actual performance against what was expected.

Entura has used a risk framework to determine a dam’s readiness to impound, such as for Murum Dam in Malaysia. Of course, some reservoirs take a long time to fill, potentially over a number of years, so this heightened level of monitoring and surveillance could go on for some time. There could also be saddle dams that experience water against them much later than the main dam.

Phase 4: Operation

Now begins what, hopefully, will be a long phase of normal operation. The dam will have an operation and maintenance manual to ensure that the dam is operated as intended and regular routines occur. Good dam safety practices must continue throughout the operational life, including dam surveillance, routine inspections, and ongoing emergency preparedness should any dam safety incidents, major floods or seismic events occur. Emergency plans should be tested regularly to ensure they are appropriate and robust.

Read our articles:

• What can dam owners do to better manage floods and avoid the blame game?
• How robust is your emergency preparedness?

During the operational phase of a dam, it is also important that comprehensive dam safety reviews (DSRs) occur every 20 years, or whenever there has been a major event or a change in standards or guidelines. The intent of a DSR is to determine the safety of the dam against current practice and the current condition of the dam. It’s important that the DSR considers the potential failure modes for the dam.

To undertake a DSR, good historical documentation for the dam will be needed. If the records aren’t great, or there are significant gaps, the DSR may require additional investigations and analysis to be undertaken.

Read our article:

• Keeping close tabs on your dams

In addition, it is critical that the public is kept safe around dams and throughout the operation of dams. In 2012 ICOLD established a working committee to identify these public safety risks, describe the international state of practice to manage and mitigate the risks, and develop a guidance bulletin on best-practice measures and public education about safety around dams.

Read our article:

• Keeping safe around dams

Phase 5: Upgrade and improvement

If the DSR identifies deficiencies in the dam, a dam safety upgrade may be needed. This is the next stage of a dam’s life. A risk framework can often be used to justify and guide these upgrades.

Read our article:

• Using risk assessment to guide dam safety upgrades

Dam upgrades may not always be due to a dam safety issue; they may also be driven by the opportunity to increase value, which may be able to be achieved through measures such as raising the height of the dam. They can also be driven by changing design standards, changes to legislation, greater understanding about extreme hazards, or (more recently) climate change impacts.

Read our article:

• Designing dams for an uncertain climate future

With a large portfolio of dams, the demand on resources (both capital and human) can be significant. A portfolio risk assessment (PRA) allows owners of dams and other water assets to see the bigger picture of how to prioritise their efforts and resources to achieve the best safety results across the whole portfolio.

Read our articles:

• Portfolio risk assessment takes dam safety programs to the next level
• Safer dams are a matter of priority

Phase 6: Decommissioning

This final phase of a dam’s life may actually never occur, as most dams continue to provide a valuable service to society indefinitely. But, with time, the needs of the community may change, or the commercial benefits of the dam may reduce. In these circumstances, the dam may be decommissioned and removed. This decision is not likely to be made quickly, and for good reason, as this is a very complex matter involving many stakeholders. A recent example is the landmark decision to remove 4 dams along the Klamath River in northern California and southern Oregon. This is the most extensive dam removal and river restoration project in US history.

Although some dams may at some stage be decommissioned and removed, more dams will always be needed to meet the world’s needs for water security, clean energy, and storage of mining tailings.

Read our article:

• Dams are crucial to climate change response and the energy transition

And so the life cycle begins, all over again.

From binoculars and boots to bytes and bots: harnessing remote sensing and AI for ecological monitoring

For power and water developments to be truly sustainable, we must preserve and protect biodiversity. But it can be difficult to look after what you don’t know about or don’t understand. In the age of Big Data, automation, AI and increasingly clever gadgets, field ecologists can now do more with less – in other words, get lots of good information very quickly and with far less cost. That’s good for projects and for our planet.  

Field ecologists spend much of our time gathering information on species occurrence, distribution, abundance, habitat requirements, and threats. We need methods to detect and quantify biodiversity that are efficient and sensitive, and not biased, invasive or destructive.  

Our job increasingly involves leveraging the advances in monitoring technology, computing power, and machine-learning methods to help our clients assess, avoid, mitigate or offset environmental impacts. Vast amounts of visual, spatial, genetic and acoustic information can now be captured using new tools such as ‘camera traps’, automated image classifiers, passive acoustic monitoring, automated species detection from audio data, and eDNA. 

Camera trapping  

Camera trap monitoring (using digital cameras activated by motion or heat) is a powerful tool for observing and cataloguing species, but it can generate enormous numbers of images. Each image needs to be viewed and tagged to create meaningful data. Until now, that’s taken up a lot of human time. Now, however, machine-learning models can automate the process of detecting and classifying animals.  

For example, the ‘MegaDetector’ is an open-source image-segmentation tool from Google that can automatically place a bounding box around a region of interest in the environment, in this case zooming in on an animal and isolating it from the background. This can be put into a wildlife-species classifier before verification by a human, raising the accuracy of classifying some species to up to 99% and increasing the speed at least 20-fold – in fact, it is estimated that approximately 5,000 images can be tagged per hour using these workflows. 

Examples of camera trap images with the MegaDetector bounding box applied

As well as detecting rare, cryptic and elusive native species, camera trapping can also detect and help to quantify the threat posed by introduced animals. Technology has even been developed that enables humane, automated feral cat and fox control: the ‘Felixer’ device uses rangefinder sensors to distinguish target cats and foxes from non-target wildlife and humans. Felixers can even be programmed to play a variety of audio lures to attract feral cats and foxes. The targets are detected via a camera-based AI system working in tandem with four LiDARs. These devices are operating in all Australian states and territories, protecting threatened species including bilbies, bettongs, rock wallabies, quolls, malleefowl, ground parrots, numbats and rare dunnarts and rodents. 

Passive acoustic monitoring 

Another recent advance that is revolutionising species detection is passive acoustic monitoring. In Tasmania, the endangered, cryptic, poorly understood Tasmanian masked owl (Tyto novaehollandiae castanops) has traditionally been detected through ‘call-playback surveys’ – experts listening for owl vocalisations in response to broadcasting recorded owl calls – but some owls just won’t play the game! Passive acoustic monitoring is a more effective method for detecting these birds, with recorders deployed and set to record from dusk until dawn. Software has been developed to graph the recorded sounds as spectrograms and then automatically detect this species’ persistent screech calls and even chattering calls. Work is underway to differentiate between adult and juvenile calls, which will help identify nearby roosting and nesting sites. With robust bioacoustic recorders and partial automation of analysis, we can detect this elusive species and identify critically important nesting sites more accurately, rapidly and at less cost. The technology can also be used to detect other species with distinctive vocalisations.  

Screeching calls of an adult Tasmanian masked owl can be heard in the audio above

Wildlife Acoustics Song Meter SM4 deployed by Entura ecologists in north-west Tasmania, within a patch of tall eucalypt forest assessed to be potentially suitable nesting habitat for Tasmanian masked owls 

eDNA, barcoding and metabarcoding 

Increasingly rapid and relatively cheap DNA sequencing techniques are also transforming biodiversity research. Environmental DNA (eDNA) is genetic material from the hair, skin, urine, faeces, gametes or carcasses of organisms that can be found in the environment. This eDNA data can be interpreted through ‘barcoding’, which uses species-specific tools to detect the DNA fragments of a single species within an environmental sample, as well as ‘metabarcoding’, which can simultaneously detect millions of DNA fragments from the widest possible range of species. eDNA barcoding is particularly useful for detecting invasive, rare and cryptic species in places that are otherwise difficult to survey.  

What’s next? 

Fauna survey methodologies are evolving fast. Soon we’re likely to see continuous, automated wildlife detection and species identification, with solar-powered detection units (camera traps, bioacoustic recorders, etc.) autonomously uploading data to the cloud. This could produce high-resolution activity maps that update in real time and at large scale. Systems that can compute and upload data autonomously and are self-sufficient in energy will allow us to obtain accurate and extensive information from almost anywhere, anytime.  

So, are clever bots and gizmos going to take our jobs? Will we never head out into the field with our binoculars again? Not quite yet (happily!), but with increasingly robust hardware, modern computing power and machine-learning, we can do more for our clients and our planet, and that’s a great win–win for us all.  

If you’d like to talk with Entura about our ecological monitoring services, contact Raymond Brereton.

About the author

Dr Carley Fuller is an Environmental Consultant at Entura. She is an ecologist with expertise in environmental impact assessments for renewable energy projects including solar, wind, hydropower, hybrid, and transmission infrastructure developments. She has a decade of experience working in multiple Australian jurisdictions and internationally in the United States, Latin America, and the Pacific as both a research scientist and consultant. Carley has a strong technical background in plant science, land-use planning, GIS and natural values assessment and completed her PhD in conservation science at the University of Tasmania. She is passionate about leveraging environmental data to provide tailored decision support for a range of stakeholders.

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Understanding the challenges of medium-sized power systems 

Power systems in the range of 200–500 MW face unique challenges, including how to incorporate increasing amounts of intermittent inverter-based renewable energy, such as solar PV and wind generation. What are these challenges, and how can they be solved? 

Large power systems, like the interconnected grid of the eastern Australian states, are well-understood. These systems have extensive engineering support and sophisticated models to handle renewable energy integration, with network-wide inverter-based renewables (IBR) penetrations ranging from 25–50% and local penetrations up to approximately 115%. Similarly, small power systems, such as those up to 30 MW found in remote mining sites, also manage high IBR penetrations, sometimes reaching 100%. 

However, power systems in the range of 200–500 MW face unique challenges. We call these systems ‘anti-Goldilocks’ power systems. Stemming from the children’s story of ‘Goldilocks and the Three Bears’, Goldilocks has come to mean something neither too big nor too small, neither too complex nor too simple – in other words, ‘just right’. An anti-Goldilocks system, on the contrary, has an uncomfortable combination of both large and small system challenges without the solutions available to a large system operator. 

Examples of anti-Goldilocks (AG) power systems in Australia and the Pacific include: 

• Fiji power system 
• New Caledonia 
• French Polynesia (Tahiti) 
• Guam 
• PNG (Port Moresby) 
• Darwin Katherine interconnected power system 
• North-west minerals power system (Mt Isa and surrounds) 
• Western Australian north-west interconnected system 
• the Tasmanian power system during low demand. 

Common challenges in AG power systems 

AG power systems share characteristics that make managing high IBR penetration both inevitable and challenging. 

1. 1. Geographical distribution and stability 

In small power systems, all generation sources are often close together, ensuring good transient stability. Large systems benefit from high interconnection levels that couple machine inertias effectively. AG power systems, however, are geographically spread out without these stabilising features, leading to difficult transient stability conditions. 

2. 2. Environmental conditions and storage 

Small systems can install enough battery energy storage (BESS) to manage fluctuations in renewable energy sources. Large systems distribute IBR across vast areas, minimising localised impacts from wind and irradiance. AG systems, however, typically have most IBR within a 100 km radius, which means that similar environmental conditions can affect all IBR at once, potentially causing sudden shortfalls in generation. 

3. 3. Rapid changes in IBR penetration 

AG power systems often have high electricity costs and small sizes relative to each IBR station. This makes renewable generation very attractive financially, and a single IBR connection can immediately cause significant penetration increases, potentially reaching 80%+ quickly and catching network operators off guard. 

4. 4. Responsibility for quality and ancillary services 

Because small systems typically have just one generator and one consumer, they tend to have straightforward responsibility allocation for the quality of supply and ancillary services. Large systems are either government-owned or regulated with established market mechanisms for these services. AG systems may lack these structures, often having multiple generating companies and consumers, complicating the provision and funding of necessary services. 

5. 5. Modelling and planning 

Large systems have developed accurate models over many years. Small systems manage with less detailed models because most errors don’t significantly impact overall accuracy. AG systems typically have poor models. The requirement for greater accuracy is only a recent phenomenon, but a greater level of accuracy has been difficult to achieve due to the lack of collaboration between customers and generators, a lack of necessary modelling skills, and a reluctance to see modelling as core business. 

Transitioning to inverter-based renewables: four horizons 

Successful operation during the transition to IBR involves navigating 4 distinct horizons: 

1. H1: conventional dominance 
   The network is dominated by traditional plants with control based on speed and voltage droop. The system can manage almost indefinitely without wide area controls during disturbances. 

2. H2: high IBR penetration (60%) 
   There is a high level of IBR penetration, say 60%. While the distributed versus wide area control issues don’t change significantly, prolonged outages of wide area control cannot be tolerated. Systems should operate without human intervention for at least 20 minutes during such failures. 

3. H3: minimal rotating machines 
   There are periods with only one large rotating machine. Planners should ensure the system can operate for 20 minutes without human intervention if this generator fails. 

4. H4: full IBR operation 
   The system operates with 100% IBR and should be designed to manage without human intervention for 20 minutes during wide area control outages. 

Solutions and optimisations 

AG power systems face significant but solvable challenges as IBR connections increase. While installing sufficient battery capacity and running rotating plants at low output or adding synchronous condensers can help, these solutions can be costly. Therefore, optimising solutions to minimise additional costs is essential. 

Entura has worked on most of the AG power systems listed above and we have found that batteries, while helpful, are only one part of the solution. Effective rules and regulations that allocate risks and responsibilities appropriately, along with a causer-pays mentality and prudent risk acceptance, lead to the more cost-effective technical solutions. 

To discuss how Entura can help you ensure the safety of your electrical assets, contact David Wilkey or Patrick Pease.

About the author

David Wilkey is the Senior Principal, Grid & Power, at Entura. David has more than 25 years’ consulting experience across a wide range of electrical engineering projects, including power system studies, power system and generator protection, generator connection rules, and primary plant electrical engineering. David’s primary interests include all aspects of electrical engineering for hydropower projects, such as hydro turbine governors, generator excitation and generator protection systems.

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Bifacial solar PV: shining light on all the angles

In the booming global solar industry, installation of bifacial panels has been rapidly overtaking conventional monofacial modules, particularly in utility-scale projects but increasingly at smaller scales (<5 MW) too. But are they the right technical investment for your solar project – and what do you need to consider?

We recommend getting to grips with the benefits, constraints and implications of bifacial modules as early in the development cycle of a project as possible. Here are some observations to get you started.

What are the advantages of bifacial solar PV?

Bifacial solar PV modules are solar panels capable of generating electric current from both sides of the panel, as opposed to monofacial panels, which generate from one side only. Sunlight can pass through a transparent top layer and be absorbed by the solar cells, while sunlight reflected off surfaces can be captured through the transparent bottom layer, increasing the overall power output and potential energy yield.

The advantages of bifacial solar modules include:

• enhanced energy yields (typically 5% and can be up to 10% when optimised at particular sites) with only minor differences in supply cost
• lower levelised cost of energy (LCOE) with greater return on investment (ROI)
• increased duration of maximised power export
• enhanced performance in diffuse light conditions, such as when it is cloudy, which can be beneficial for the stability of hybrid power systems
• greater power density achieved in space-constrained sites
• better end-of-life outcomes, as glass is more readily recyclable than plastic polymers used for the backsheet of monofacial modules
• some manufacturers also claim improved durability and longevity of panels due to double glass construction rather than the glass and polymer backsheet of monofacial modules. This is claimed to be more resistant to environmental factors such as moisture, humidity and fluctuations in temperature. It has also been anecdotally suggested that the glass backface increases protection from water ingress and resistance to corrosion.

Are there any potential downsides?

Bifacial modules typically have a front-side glass thickness of 2 mm with 2 mm on the rear side, compared to monofacial modules which have 4 mm on the front side only. This can increase susceptibility to hail damage, which may require further mitigation measures in hail-prone areas and could increase the cost of insurance.

What’s albedo and why does it matter?

The more reflective a site, the better its prospects for gaining the bifacial edge. Generally, there is a linear correlation between the ground reflectance conditions (albedo) at the site and the power gain from the backside of the bifacial panels. Albedo is also the single largest factor driving bifacial gain.

But a site’s ground conditions will change over time, so one of the most important considerations when calculating the possible benefits of deploying bifacial over monofacial solar modules is determining what the long-term average albedo is at the site. Many factors can play a part in the way the albedo is modelled – including the intended use of the site once the solar plant is built, revegetation strategies, grazing livestock, the frequency of droughts and flooding events, precipitation volume and water pooling, how green the grass is, and the colour of the earth. The highest albedo factors and bifacial gain will be in conditions such as frost or snow, with its high level of reflectance. The lowest albedo factors are achieved on surfaces such as dry asphalt or grasslands.

Is more height a good thing?

Another major factor driving bifacial power is the height of the installation. Bifacial power gain increases with installation height as a greater angle is available for reflection of direct and diffuse irradiation to the rear side of the modules. This gain is most prominent typically between the installation heights of 0.5 and 1 metre before levelling out above 2 metres. In areas prone to flooding, higher installation may also provide extra resilience to increasing weather extremes.

An important consideration here, however, is that although higher installation may increase energy yield and financial returns, there may be considerable additional capital costs and greater complexity of construction of the mounting infrastructure, particularly for longer piles.

What’s the right ground cover ratio?

When the percentage of area covered by PV modules increases, the bifacial gains decrease. If more ground is covered, more area is shaded, and there will be less reflection to the rear side of PV modules. Often there is an incentive for developers to maximise the solar DC power capacity of a given site to avoid costly additional land agreements and minimise the project footprint. However, this can result in a high ground cover ratio (GCR) which can cause shading between rows. This increase in ground shading reduces backside power and energy yield gains (although it can sometimes be mitigated by the ‘backtracking’ capability of single-axis trackers).

Recently, we have been seeing developers take a more conservative approach with this in mind, preferring a GCR below or approaching 0.30.

What about shade from the mounting structure and cables?

Increasingly, manufacturers of mounting structures are looking towards maintaining structural integrity of their equipment while also minimising shading. String cabling can also be a cause of rear shading, so they should be fixed underneath the torque tubes of single-axis trackers (SAT) or underneath the mounting structure supports to minimise any impact. We are noticing an increasing focus on consistency of construction in this regard and the inclusion of this check on installation test certificates as minor shading on one module has the cascading effects of derating the entire string of modules.

Could spikes fry the electricals?

Although asset owners are most interested in the potential for greater energy yield from bifacial modules, it is necessary to also assess the electrical maximum power point voltage and current limits caused by spikes during high irradiance events. These spikes can be caused by a range of environmental factors which may be specific to sites. These include early morning frost at low temperatures, increasing sunlight irradiance at the edge of lensing clouds (magnifying glass effect), snowfall or flooding/water pooling.

In some areas which experience high ground albedo in conjunction with technical designs for favourable backside power gain, the maximum instantaneous bifacial gain can be as much as 15 to 25% for some Australian contexts, which can impact the allowable number of modules in a string as well as the input parameters to combiner boxes, inverters and cables throughout a project.

What’s next under the sun?

Solar is an exciting sector of rapid, continuous innovation, so there will no doubt be ongoing technological evolution with new implications and applications to explore. Regardless of whether bifacial panels are right for your project at this stage, it’s worthwhile considering all the options that might work best for your site. In the transition to net zero, every solar installation has a crucial role to play. The better the yield and value that can be achieved from a solar project, so much the better for the developer, the community, our environment and the future.

If you need support to assess energy yield, design, and technical considerations for your solar project, please contact our business development managers, Patrick Pease (Australia) or Shekhar Prince (international).

About the author

Lachlan McKenna is a renewable energy engineer in Entura’s renewables development team. He works on solar, wind and BESS projects from concept and design through to operations and repowering in locations throughout Australia and the Indo-Pacific region. Prior to working for Entura, Lachlan gained experience in the commercial and industrial rooftop solar sector and European offshore wind industries.

See our previous articles on how to achieve solar success:

Changing the climate future 

The future isn’t what it used to be. The future we now expect is one of even more intense rainfall. What can we do about it? 

In Australia, there is now expected to be a 41–88 % increase in intense rainfall assuming a fossil-fuel development emission scenario by 2090, working from a 1961–90 climate base. In Tasmania, our previous vision of 2090 was an expected intense rainfall increase of only 16.3 %. So the future is looking different, with more intense rainfall. New projections are making the present and near future look different too. We now understand that there will be a 16 % increase to the current climate (2021–40) for 3-hour-duration rainstorms (since the 1961–90 period). In other words, the ‘old future’ is now and the ‘new future’ is different from what we thought. 

In December 2023, draft changes to the Australian Rainfall and Runoff (ARR) climate change advice were released, changing many of our projections. Between the 1961–90 rainfall data used to calculate the intensity-frequency-duration of most rainstorms and the ‘current’ climate (2021–40), there is expected to be a 1.3 °C rise in global temperature (noting that this comes on top of the already 0.3 °C increase in global temperature from the 1850–1900 pre-industrial period to 1961–90). So for a fossil-fuel development emissions scenario (SSP5–8.5, Meinshausen et al 2020), what we previously projected for intense rainfall by 2090 is now our projection for some storms in the ‘current’ climate (2021–40).  

If the ‘old future’ is our new reality, what could the actual future be?  

As of March 2024, the future is projected to be hotter than previously expected, and intense rainfall is expected to increase proportionally more for every degree of temperature rise. There could be a small increase in catchment losses, but these are expected to be overwhelmed by the increases in intense rainfall. There is also a better understanding of the uncertainty in the modelled projections. 

An example in Tasmania 

In Tasmania, water is fundamental for the environment and community, and the importance of our understanding of water is heightened by our reliance on hydropower for the bulk of our electricity. However, the climate changes discussed here are less about longer term water and energy yields than about the intense rainfall associated with flooding.  

For Tasmania: 

• Prior to the draft December 2023 ARR advice on climate change (Engineers Australia, 2023), with the SSP5 emission scenario with 8.5 W/m² radiative forcing there was projected to be a 16.3 % increase for all rainfall durations by 2090. The December 2023 draft advice for this scenario is that by 2090 the increase in intense rainfall is expected to be 41–88 % over the 1961–90 climate base (that is, the data you can get from the Bureau of Meteorology as the 2016 intensity-frequency-duration rainfall data). This means 41 % for 24-hour and longer duration rain storms, and up to 88 % for durations of 1 hour and shorter. These apply across Australia for rarities from an exceedance per year to the probable maximum precipitation event. There are several papers on the subject, for example Visser et al (2022) and Wasko et al (2024). 
• For 1 hour and shorter duration storms, which are important for drainage from building roofs and for most town local stormwater systems, the current period (2021–40) has a 20 % increase in intense rainfall over the climate base (1961–90). This means that all designs made over the last few years using a 20 % increase in rainfall to allow for a future climate will still work as expected for the time being. But after about 2040, these designs are unlikely to perform as expected. 
• For 3-hour-duration storms there is expected to be a 16 % increase over the climate base (1961–90) for the 1.3 °C rise in temperature to the ‘current’ period (2021–40). This means that what we thought would only happen in the more distant future is expected to be occurring now. The reasons we say this is ‘expected’ is that we won’t know for sure until we look back on this period with hindsight. 
• For the 24 hour and longer durations, the current period (2021–40) has an 11 % increase in intense rainfall over the 1961–1990 climate base. With the non-linear relationship between rainfall and runoff, the increase in peak stream flood flow is expected to be higher than 11 % for most larger rivers, such as those that flow to our dams. 

Impacts on decision-making and design 

Following the Sixth Assessment Report in 2023 (AR6) by the United Nation’s Intergovernmental Panel on Climate Change (IPCC) (https://www.ipcc.ch/assessment-report/ar6/), and anticipating the next one due around 2029 – and with science and engineering understanding increasing all the time – it’s likely that our projections of the future scenarios and understanding of the past will continue to evolve. Obviously, infrastructure that’s built stays built, but can be augmented. Standards and methods can’t change every year for practical reasons, but those of us impacted by climate and water are wise to remain up to date and always use the most contemporary knowledge. Asset owners, regulators, consultants and the community need to pay attention as the climate changes. 

When the goal posts shift, we need to take stock of previous advice provided with old rainfall data, and consider how to include current rainfall data in new advice. As we go forward, we also need to be more careful in our language about how we reference the past, current and future. 

When making decisions for infrastructure that will last at least 100 years and take 5 to 20 years to plan, design and build, such as sizing dam spillways, a range of risk mitigation strategies are required for managing an uncertain future (for example https://entura.com.au/designing-dams-for-an-uncertain-climate-future/). When reviewing the performance of existing systems, defining the ‘current climate’ is important. Climate change isn’t something just for future scenarios – we’re living it now. 

Strategies to support better climate-related decision-making include: 

• using the current best knowledge 
• understanding data and model uncertainty 
• understanding natural climate variability on seasonal to decadal time scales 
• understanding that future climate scenarios are all possible 
• applying sensitivity analysis 
• using multi-criteria assessment 
• using staging strategies 
• providing options in design for changing levels of service. 

If, for example, we were designing a new building to be built soon near a watercourse, all the following approaches could be considered:  

• Design the level of the earthworks and finished hardstand levels to meet the level of service in the ‘current’ climate (e.g. 2021–40), considering a freeboard over the raw modelled river levels to account for uncertainty in any modelled results. 
• Make allowances in the construction to address future climate scenarios (e.g. SSP5 2090) and build now only what’s prudent. 
  • Allow space for a future flood wall and its footings, potentially building the footings now if integrated into the current site works. 
  • Consider space for future flood gates on site entry, and consider their storage and other requirements that are best allowed for in the current construction (such as communication and power conduits under hardstand areas, and space in control rooms). 
  • If a flood wall is not desirable or if construction access for building a flood wall is not going to be practical in the future once the site is developed, it may be better to lift the site levels or build the flood wall as part of the current works. 

Uncertainty has always been part of engineering design, as has making decisions with imperfect knowledge. Climate systems in particular are subject to a wide range of natural variability over a wide range of times scales. What’s different now is that the future is more obviously uncertain and changing more rapidly. For example, where once we could use rainfall tables in textbooks for decades, now it seems that every few years there are new projections from the IPCC about large or small changes in our understanding. It’s a dynamic time for making decisions. But this isn’t all bad news. 

Looking forward 

If you’re planning an improvement project and the future is expected to bring larger floods, your return on investment may be quicker than expected. With the expected increases to rare rainfall intensities and the increasing uncertainty, there should be more confidence in investing in solutions to improve the performance of surface water infrastructure. In the same way, you’ll get a faster return on your investment in improving your engineering skills related to climate, hydrology and hydraulics of surface water systems and associated infrastructure design. 

While considering the worst, we hope for the best. The fossil-fuel development emission scenario (SSP5) is based on us continuing the polluting hydrocarbon-based developments of the past. Entura is actively supporting our clients to pursue low emissions developments and more renewable energy for a better future. A best-case scenario is shown in the diagram below as SSP1 (called the sustainability scenario). In this scenario, with 2.6 W/m² radiative forcing, the projection for 2090 would be an increase of 1.7 °C in global temperature over the 1961–90 climate, and only a 14–27 % increase in intense rainfall (for 24 hour and longer to 1 hour and shorter durations respectively).  

To prevent the extreme global temperatures projected to arise from polluting the atmosphere, it’s up to all of us to keep changing for a better future. 

Figure of projected temperature increases associated with AR6 shared socioeconomic pathways relative to 1961–90 (shaded in grey) and their associated uncertainty (Engineers Australia, 2023)  

References 

Engineers Australia (2023) Update to the Climate Change Considerations chapter in Australia Rainfall and Runoff, Department of Climate Change, Energy, the Environment and Water https://storage.googleapis.com/files-au-climate/climate-au/p/prj2aec7b7ec59ab390bffc6/public_assets/Draft%20update%20to%20the%20Climate%20Change%20Considerations%20chapter.pdf.  

Meinshausen et al. (2020). The shared socio-economic pathway (SSP) greenhouse gas concentrations and their extensions to 2500. Geoscientific Model Development, 13(8), 3571–3605. https://doi.org/10.5194/gmd-13-3571-2020.  

Visser, Kim, Wasko, Nathan and Sharma (2022), The Impact of Climate Change on Operational Probable Maximum Precipitation Estimates, Water Resources Research, https://doi.org/10.1029/2022WR032247. 

Wasko, Westra, Nathan, Pepler, Raupach, Dowdy, Johnson, Ho, McInnes, Jakob, Evans, Villarini and Fowler (2024), A systematic review of climate change science relevant to Australian design flood estimation, Hydrology and Earth System Sciences, https://doi.org/10.5194/hess-28-1251-2024. 

If you’d like to talk with Entura about your water project, contact Phillip Ellerton.

About the author

Dr Colin Terry is a civil engineer at Entura with three decades of experience in Australia and New Zealand. His experience includes modelling, planning, design and construction support. He has worked on multidisciplinary projects across various parts of the water cycle including catchment management, water supply, hydropower, land development, transport, and water quality in natural systems – with a focus on surface and piped water.

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Ten tips for developing your engineering career

From Baby Boomers to Gen Alpha, the generation names and characteristics come and go – but despite the changing working styles and preferences of older and younger engineers, some things stay the same. Developing good engineers still calls for many elements that have shaped countless careers over time: people who were willing to share their knowledge and experience, opportunities to develop and refine the engineering craft, and mentors to support us, believe in us and help us make the next step.

I’ve been reflecting on these dynamics at this senior point in my 34-year career – and I’d like to share some tips to help set younger engineers on a path towards achieving a satisfying, successful career.

Tip #1 – Never stop learning

Graduating with a formal engineering qualification is only the first milestone in your learning. Explore whether there are postgraduate courses that can help you grow and open up opportunities that interest you. It isn’t easy to balance postgrad studies with work – let alone with the family responsibilities that many people experience in their early/mid adulthood. You’ll need to think carefully about how much time you can devote – and how to maintain a healthy work/study/life balance.

Also look at what your workplace can offer in terms of internal programs, such as broad-based leadership programs. An industry body will often offer short courses and will also provide networking opportunities where you can learn from other people – so join a professional association. Beyond formal courses, you can use your development plan to your advantage by identifying areas that interest you and seeking variety in the kinds of tasks and projects you are assigned.

Whatever career stage you’ve reached, stay interested, interact, and keep asking questions. It’s a great antidote to becoming a ‘know it all’ or getting stuck in a rut! At the end of each year, ask yourself, ‘What have I learnt that’s new?’ If you can’t think of anything, then maybe you’re playing it too safe and it’s time to change things up a bit.

Tip #2 – Seek mentors

Mentors – whether formal or informal – can give you technical insights and can also help guide your broader professional journey. Use mentors to extend your learning beyond your allocated tasks, such as how to be a good consultant, or just broaden your understanding. Think broadly about who you could seek out as mentors along your career journey. For example, some of the members of independent review panels have become de facto mentors to me. Value your mentors, and try to give something back or pay it forward to the next young engineer.

Tip #3 – Pursue breadth as well as depth

Breadth is as important as depth. Try to achieve more breadth before you specialise, because breadth will make you a better expert (where you have depth) and extend your value as a consultant. For me, experience in designing and constructing dams and hydropower as well as stints in hydrology and modelling gave me a more holistic understanding of dam projects. Try to get some experience in other related disciplines, so you are better placed to manage multi-disciplined projects; and get some construction experience so you can see how your designs translate on the ground.

The value of broad experience is evident in the 16 competencies set out by Engineers Australia for ‘Chartered Engineer’ status. Use them to work towards becoming chartered – a target that every engineer should strive for.

Tip #4 – Seize opportunities

Only you can act to take the opportunities that emerge in your career, to make the most of them, and to learn from them. If you think too long, the opportunity may disappear or someone else may seize it. This will sometimes require sacrifices – such as periods away from home, which can be hard – but sometimes a little adversity can really spur your professional and personal development. Opportunities could be a particular project, an opportunity to work with someone you want to learn from, or an interesting career episode in a different place or a different role.

Tip #5 – Take some risks

If someone you respect believes you can do a role on a project, maybe you should too. Stretching yourself will help you develop. Jumping – or being thrown– into the deep end can be a great way to learn, as long as you’re supported so you don’t sink. Talk to your mentors and managers about how they can support you to thrive rather than flail. Remember that mistakes and failures are not the end – they are excellent stimulus for learning, and you certainly won’t be the first to experience them.

Tip #6 – Be strategic

Your employer’s responsibility is to create an environment in which you are able to develop, but ultimately your career is your responsibility. What do you need to learn or achieve in order to get where you want to end up? How can you position yourself so that you’re ready when opportunities emerge? For me, this was the need to have a Masters degree to take on team leader roles on bank-funded international projects – which spurred me to return to study. You could use the competencies for Engineering Chartered status as a benchmark to identify gaps and then work to fill them.

Tip #7 – See things through from start to finish

Look for opportunities to be involved in a project from inception through to commissioning. You will learn a great deal from seeing how the investigations and decisions taken in the design play out in the actual conditions on site as well as the constructability and the performance of the structure. These experiences will shape your expertise, how you operate in the future as an engineer, and the advice you give your future clients. This is equally relevant for other programs of work, seeing the program from a conceptual stage to an operational stage.

Tip #8 – Build your consulting skills

If you want to work in consulting, you need to become more than a technical expert. An ideal consultant needs technical expertise, but also needs to be able to engage effectively with clients, to communicate well (both in writing and orally), to be creative and solve problems, and to manage and deliver projects. These skills are valuable for everyone, regardless of your role. Taking up different roles through your career can also help you see things from different perspectives and become a better consultant. Every experience helps to build the consultant you become.

Tip #9 – Listen to feedback

Even if it’s uncomfortable to receive, seek out feedback and use it constructively to learn more about yourself, your skills and how you interact with others. Everyone has facets in their knowledge, performance and personality that can be enhanced. The more you can see yourself through the eyes of your colleagues, the better you’ll be able to play to your strengths and work on your weaknesses. In the end, many engineering projects require a team to deliver, so if you know your strengths and weaknesses, you can create a balanced team that capitalises on the synergies.

Tip #10 – Remember the circle of life

What goes around comes around. In the early stages of your career, it’s natural to expect support and development. Eventually, as you progress, your expectation should shift to helping develop others. I believe that this cycle should be faster than most people would expect. You don’t need to wait decades. Once you have been doing something for a few years, you can help others, and by doing so you will reinforce your learnings and improve your ability to explain complex technical elements. Developing others will also develop you.

I hope that other Baby Boomers and Generation Xs are inspired by these tips to reflect on your own experiences, share your recipes for success, and look out for where you can help others grow. It’s in all of our interests for the engineering profession to thrive.

Head to our careers page for current opportunities at Entura.

About the author

Richard Herweynen is Entura’s Technical Director, Water. He has more than three decades of experience in dam and hydropower engineering, and has worked throughout the Indo-Pacific region on both dam and hydropower projects, covering all aspects including investigations, feasibility studies, detailed design, construction liaison, operation and maintenance and risk assessment for both new and existing projects. Richard has been part of a number of recent expert review panels for major water projects. He participated in the ANCOLD working group for concrete gravity dams and was the Chairman of the ICOLD technical committee on engineering activities in the planning process for water resources projects. Richard has won many engineering excellence and innovation awards (including Engineers Australia’s Professional Engineer of the Year 2012 – Tasmanian Division), and has published more than 30 technical papers on dam engineering.

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Breathing new life into Australia’s aging wind farms

The wind industry, well-established in Europe for decades, took baby steps onto Australian soil in the late 1980s and 1990s. By the early 2000s, Australia’s new wind industry was ready to take off. Given that wind farms usually have a design life of anywhere between 15 and 30 years, our earliest wind farms are now reaching retirement age. The industry therefore faces a new set of challenges. Can these older wind farms continue to serve their important role in Australia’s clean energy transition or are they at their end of life?

So far, few wind farms in Australia have been decommissioned, dismantled and removed from the land. With many of our older wind farms sited to capture the best wind resources, there’s every reason to try to continue using these sites to harness wind energy.

One option is to squeeze more years out of the wind farm through effective maintenance and supportive analysis to ensure it is safe to do so while accepting that there may be increasingly frequent outages and increased maintenance costs to keep the wind turbines in service. However, although operation beyond the nominal life of a wind turbine is theoretically feasible, old wind turbines can’t keep spinning forever and will need to be stopped at some stage.

Other options for aging wind farms are refurbishment of some parts of the turbines, or full ‘repowering’ with completely new machines. This could also include a full redesign to accommodate larger turbines or to incorporate solar or battery energy storage systems.

An example of rejuvenation

Small grids may be some of the first to need to consider what to do about old wind farms. As an example, Hydro Tasmania’s Huxley Hill Wind Farm on King Island has three 250 kW wind turbines that were installed in 1998, and two 850 kW wind turbines that were installed in 2003.

For Huxley Hill Wind Farm, the King Island electricity load has not changed much over time, and offsetting diesel using renewable energy continues to make perfect sense.

For this site, the owner opted for a like-for-like replacement of nacelles (generator, gearbox, yaw system) of the Nordex 3 x N29 250 kW and potentially for the 2 x Vestas V52 850 kW wind turbines. This decision was partly about the good economics and sustainability of reusing existing infrastructure, and also because wind turbines of this size continue to suit the project so well.

When the wind farm was constructed 20+ years ago, the installed wind turbines were considered modern, large wind turbines. These days, the same suppliers do not offer anything less than 2 MW in capacity, with rotor diameters greater than 110 m. The lack of availability of what are now considered smaller wind turbines (say 1 MW) poses challenges for some small projects. At the scale of less than 1 MW, there are now few proven wind turbine options. At an even smaller scale (<100 kW), solar PV now dominates.

When any existing infrastructure is to be retained to support life extension of old wind turbines, such as at Huxley Hill, it’s crucial to confirm that it is still suitable and safe. This can include various techniques and activities, including:

• physical inspection by technicians and engineers
• excavation of the foundation backfill cover to reveal the tower-foundation joint and inspect corrosion and remediation
• surveying the tower and blade condition using drones
• surveying the tower verticality
• surveying the thickness of tower sections
• ultrasonic testing of bolts
• eddy current testing of welds to detect any flaws
• reviewing data from the turbines to refresh understanding of the actual wind regime, reassess fatigue loads and estimate remaining life.

Another important consideration when rejuvenating older wind farms is to consider the potential for adding solar or battery energy storage. With solar now more viable than when Huxley Hill Wind Farm was conceived, a 1.5 MW solar farm has been added to augment the wind generation.

Starting over with full repowering

Because the Australian wind industry is still relatively young, there is not yet an established practice or precedents for full repowering. However, in Europe, hundreds of wind farms have been repowered, often massively increasing output by using fewer but much larger modern turbines.

Repowering at around 25 years seems the most likely timeframe for most Australian wind farms – but few have yet reached this age. Ultimately, market factors will determine when repowering provides the best financial return.

Even though we’re still just on the brink of Australia’s repowering journey, it’s never too early to start considering the complexities and implications and assessing all options.

Repowering won’t be simple or quick. The development process for repowering NEM-connected wind farms is likely to be just as challenging as developing a new wind farm on a greenfield site.

The concept of ‘repowering’ involves a range of options for replacing old wind turbines and associated footings and electrical balance of plant with new, but it’s unlikely that much of the existing infrastructure and balance of plant will be able to retained if larger, modern turbines are selected. The layout of the wind farm is also likely to need revision to accommodate longer blades.

Planning approvals need to start just as early, as should the process of renegotiating with hosts, neighbours and communities. People may be concerned about the impacts of much taller turbines and the logistical issues of getting them to the site, as well as arrangements for the dismantling, removal and disposal of the superseded technology and infrastructure.

Repowering with bigger and more powerful turbines is also likely to involve re-permitting and negotiating a new grid connection agreement – neither of which are certain, given the cumulative impacts that may have emerged over time and any changes to rules and regulations since the wind farm was first developed.

By planning early for repowering, developers can get ahead on these issues as well as on condition assessment of the assets, decommissioning plans for old turbines, new studies that might be needed (such as bird monitoring), and new wind measurements for taller, modern wind turbines, perhaps using modern wind measurement technology such as lidar.

While some repowered wind farms will very likely incorporate new battery energy storage systems (BESS), they are less likely to deploy large-scale solar as a default, given that many of the best original wind sites in Australia are coastal or hilly, particular those in the south of the country. Nevertheless, the potential for co-located renewable generation, storage and loads is worth exploring. 

Don’t wait for trouble – start planning now

We suggest that wind farm owners take action now to deepen their understanding of the condition and present value of their assets, and explore the full range of short-term and long-term options available through a feasibility and options study. After all, in such a dynamic market and technology landscape, and with the potential for aging assets to deteriorate or fail, decisions about end of life may need to be made earlier than expected.

About the author

Andrew Wright is Entura’s Senior Principal, Renewables and Energy Storage. He has more than 20 years of experience in the renewable energy sector spanning resource assessment, site identification, equipment selection (wind and solar), development of technical documentation and contractual agreements, operational assessments and owner’s/lender’s engineering services. Andrew has worked closely with Entura’s key clients and wind farm operators on operational projects, including analysing wind turbine performance data to identify reasons for wind farm underperformance and for estimates of long-term energy output. He has an in-depth understanding of the energy industry in Australia, while his international consulting experience includes New Zealand, China, India, Bhutan, Sri Lanka, the Philippines and Micronesia.

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Designing dams for an uncertain climate future

Dams are critical infrastructure for water supply, irrigation, energy production, flood protection, or multiple purposes. They are usually designed to last at least 100 years, yet with good maintenance and appropriate dam safety practices, dams can continue to perform as designed for centuries. But what about climate change? The circumstances in which a dam operates may be very different in the coming decades – and exactly how these changes will play out in different regions is impossible to predict with certainty. 

Dams are designed to continue to perform safely in extreme events, such as major floods and earthquakes, to avoid the high economic, environmental, and social consequences of dam failure. When the consequence has the potential to be extreme, the flood that the dam will need to be designed for is, in Australia, the ‘Probable Maximum Flood’ (PMF), while in some other parts of the world it is often the 1:10,000 annual exceedance probability (AEP) flood.

But even if standards or guidelines are clear about the ‘return period’ of flood that the dam should be designed for – is it still as simple as reading the magnitude of the flood discharge off the flood frequency curve as has been done in the past? These days, it is not so simple. 

Exploring the inherent uncertainty in the flood frequency curve

Part of the reason for more complexity is that we have greater computing power today to be able to explore the uncertainty in our flood frequency curve.  Predicting extreme flood events (such as the PMF) is not an exact science and involves many variables which are often not well characterised. As a result, there is significant uncertainty in predicting floods, particularly extreme floods. If this uncertainty is presented, the flood frequency curve is no longer a single line but a band. The more extreme the flood event, the wider the uncertainty band. Although the flood frequency curve shown below is fitted directly to measured flow data, the uncertainty bounds are similar regardless of the approaches implemented to derive the flood frequency curves.

So, what flood should the dam be designed for? Should it be the median best estimate, or should it take into account some of the uncertainty? This is the first challenge, and it is there whether we consider climate change or not.

Adding the extra uncertainty of climate change

Climate change doesn’t stand still. This adds even more complexity to the flood prediction challenge. What is the impact of climate change on extreme events now, and what will it be as time goes by? Numerous studies of climate change impacts suggest that there will be greater variability in extreme temperatures and extreme rainfall, and that extreme events may become more frequent. As a result, the magnitude of extreme flood events, for which dams must be designed, will likely increase with time.

Changes in the magnitude or frequency of extreme floods will depend on projections of future temperature, emission scenarios and the models used to simulate the changes. Even with a ‘middle of the road’ emission scenario (such as the IPCC’s SSP2–4.5 scenario) that results in a median global temperature increase of 3 °C (compared to preindustrial temperature baseline) by the end of this century, there could be a 23% increase in 24-hour extreme rainfall depth. But this is only one of the scenarios; some are more extreme, some show less increase, some show more. The increase is greater for higher emission scenarios and for shorter duration storms. Ultimately, an increase in rainfall depths results in an increase in flood magnitudes.

Guidance on climate uncertainty in dam design is limited

Currently, most standards and guidance documents are silent on how climate change should be applied in the design of spillway capacities for dams to safely pass these extreme flood events. However, the International Commission on Large Dams (ICOLD) Bulletin 142 on the Safe Passage of Extreme Floods (2012) indicates that there is uncertainty associated with the resulting flood estimates because of uncertainties in the hydrometeorological data used in determining the design flood. In addition, there may be changes in future methods for the development of design floods, changes in the future condition of the catchment (e.g. due to deforestation), and changes in rainfall conditions due to climate change. All of these have the potential to increase the magnitude of the future design flood.

This 2012 bulletin encourages strategies for planning spillway arrangements with consideration of floods exceeding the design flood (i.e. checking the robustness of the spillway flood design capacity from a dam safety risk perspective). This demonstrates that more than a decade ago the international dam engineering community was already promoting consideration of climate change resilience when designing new dams and upgrades of existing dams.

The more recent ICOLD Bulletin 170 on Flood Evaluation and Dam Safety (2018) states that although projected changes in climate are generally expected to increase flood risk in many parts of the world, understanding the impact on flood risk is subject to considerable uncertainty. It states that one of the main impacts of climate change will be to increase the uncertainty associated with the estimation of extreme floods.

There are tools available now that can be used to look at climate change impacts on extreme rainfall events, mainly around changing rainfall inputs to rainfall–runoff models based on climate advice, or else through using stochastic climate generators. However, this 2018 ICOLD bulletin also warns about complex numerical modelling and the ‘black box effect’ of accepting results without verification or critical consideration. It stresses that the intrinsic hydrological uncertainty will always remain no matter how clever or complex the numerical modelling.

Practical suggestions for dealing with uncertainty

Given that dams are designed for the long-term, it is crucial to consider the uncertainty of floods and the potential impacts of climate change. Climate impacts are being discussed increasingly by dam owners, dam engineers and dam regulators – and guidance on how best to deal with climate change will come eventually. This review article, ‘Climate change impacts on dam safety’, provides a good summary and some thoughts about approaching the issues in a framework based on dam safety risk.

In the meanwhile, we’ve developed some practical suggestions for dealing with intrinsic hydrological uncertainty and the increased uncertainty due to climate change, whether you’re working on new dams or upgrades to existing dams:

1. 1. Determine the consequence category for the dam. If this is ‘High’ or ‘Extreme’, take a more conservative view as to the acceptable flood capacity.
2. 2. Try to quantify the uncertainty, based on current climate conditions, as part of any flood study for a new dam or the updated flood study for an existing dam as part of a dam safety review. The Monte Carlo simulation approach to flood estimation is very useful in this regard.
3. 3. Consider some of the additional uncertainty due to climate change, based on various future climate change scenarios using GCM modelling for the region in which the dam is located.
4. 4. Undertake sensitivity assessments for spillways for new dams, or upgrades to spillways on existing dams, based on the uncertainty presented in the extreme flood events.
5. 5. If the incremental cost increase to the overall project cost is relatively low for increasing the spillway capacity to accommodate climate uncertainty, build resilience into the design as suggested by ICOLD Bulletin 142.
6. 6. If the incremental cost is significant, apply the ALARP principle for upgrades to existing dams. For new dams, assess the likely benefits and costs in detail using a risk-based framework (and consider suggestion 8 below).
7. 7. For an existing dam or new dam, consider the opportunity to stage a spillway upgrade such that the dam is made compliant for the current climate scenario with planned future upgrades that allow flexibility to meet future climate scenarios.
8. 8. Where decisions about designing for climate uncertainty become complex, consider an independent technical review panel to provide appropriate technical governance on a risk-based decision.

If you would like to speak with us about how climate change could affect your new or existing dam, please contact Richard Herweynen or Prafulla Pokhrel.

About the author

Richard Herweynen acknowledges the input of his colleagues Prafulla Pokhrel (Principal Consultant, Hydrology) and Paul Southcott (Senior Principal, Dams and Headworks) in writing this article.

Richard is Entura’s Technical Director, Water. He has more than three decades of experience in dam and hydropower engineering, and has worked throughout the Indo-Pacific region on both dam and hydropower projects, covering all aspects including investigations, feasibility studies, detailed design, construction liaison, operation and maintenance and risk assessment for both new and existing projects. Richard has been part of a number of recent expert review panels for major water projects. He participated in the ANCOLD working group for concrete gravity dams and was the Chairman of the ICOLD technical committee on engineering activities in the planning process for water resources projects. Richard has won many engineering excellence and innovation awards (including Engineers Australia’s Professional Engineer of the Year 2012 – Tasmanian Division), and has published more than 30 technical papers on dam engineering.

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Monitoring tailing dams with unified data visualisation

This article is based on a recent presentation by Richard Lindqvist, a data integration specialist with Entura, at the ANCOLD Tailings Dam Operators Forum 2023. Richard describes the need, opportunities and barriers to adoption of advanced monitoring systems.

Tailings facilities are crucial for preventing any spread of mine tailings into surrounding land and waterways. Some tailings dams are among the largest engineered structures in the world. Like all dams, they must be managed to protect downstream communities and the environment from harm.

The catastrophic collapse of a tailings dam in 2019 in Brazil focused intense global attention on the safety of tailings facilities. In 2020, a new Global Industry Standard on Tailings Management (GISTM) was released.

The global standard emphasises the need for appropriate monitoring of tailings facilities throughout their lifecycle – from design to closure – to aid in the mitigation of risk.

Advanced monitoring systems can assist greatly in meeting and exceeding the requirements of the GISTM. Here we’ll discuss the potential of telemetry, automation and meaningful visualisation of monitoring data – and the benefits that can flow from implementing such a system at your site.

The GISTM sets the context for monitoring

Accurate, meaningful and continual data from monitoring systems forms an important part of a comprehensive and integrated knowledge base, which is a core principle of the GISTM, particularly with respect to Principle 7 of the standard.

Monitoring data is to be assessed at the frequency recommended by the Engineer of Record (EoR). Any conditions exceeding the dam’s critical operating parameter ranges (COPs) must be addressed promptly through trigger action response plans (TARPs) or critical controls.

The COPs are parameters that if exceeded have a real risk of leading to a dam safety incident. Each COP has a TARP. Careful and regular monitoring of COPs can identify early signs of a potential safety issue and allow rapid intervention before the trigger level is reached.

These requirements set the context for monitoring methods, and reinforce the importance of accurate, up-to-date, meaningful information that tells a clear and timely story about the facility’s current state, trends and potential concerns.

New technologies have changed the face of monitoring

As technology has progressed, new opportunities have arisen for monitoring tailings facilities, with enormous benefits in efficiency, immediacy and accuracy. Now, COPs, TARPs and data quality can be assessed in near-real-time using automated processes – enabling efficient and early identification of faults, such as during construction activities. Time spent collecting field data and maintaining systems is minimised, and the saved time can be reallocated to dam inspections and deeper assessment of data trends. End-to-end connectivity allows multiple sources of telemetry data and operational data to feed immediately into a unified and user-friendly visualisation platform, supporting understanding and decision-making. Monitoring data can also feed proactive and predictive maintenance in asset management and operations.

Opportunity abounds, but barriers remain

As with any new standards and systems, there are likely to be some barriers or challenges in moving from a design or concept to reality. In our experience, some common factors include resistance to change, the potentially significant cost to invest in the new technology needed for an efficient and integrated system, and the balance of resourcing between automated versus field data collection and processing. Other common hurdles are integration with existing systems and workflows and the data security and governance standards to be met. Staff training and succession planning can also be a challenge but are essential to maintaining the necessary knowledge base.

None of these challenges are insurmountable – and the effort to overcome them will be repaid by the immense benefits in operational intelligence, efficiency and reliability that advanced, automated, integrated systems can deliver.

A real-life example of an evolving monitoring system

Entura has been on a journey with a large mining client for nearly 15 years, continually improving the facility’s monitoring solutions. Initially, we used our own Ajenti telemetry loggers and Ajenti Data Management System (ADMS) before progressing to the integration of other vendors’ logger data to the ADMS. We are now moving forward in using OSI Pi to integrate a broad array of data sources for our clients, presenting them within an accessible and adaptable visualisation platform.

Historically, data was retrieved manually from field loggers for processing into spreadsheets and manual analysis of charts. With data retrieval via telemetry, along with automated analysis and visualisation, this time can now be spent reviewing TARP alerts and in-depth assessment of data.

System reliability and robustness has been another key factor in our work with our clients – with improvements such as fit-for-purpose enclosures (316 stainless steel), solar power installation and the ability to assess operational data such as battery voltage and signal strength. This is reducing the physical maintenance needs at monitoring sites and replacement of enclosures or batteries. The focus can now be on routine inspections of dam conditions rather than managing the monitoring network.

Effective record-keeping is essential when managing a large monitoring network. The new system enables a rich knowledge base to be compiled, stored and interrogated. Site metadata and documentation can be hosted on the visualisation platform, including calibration and installation reports, FATs and SATs (factory and site acceptance tests), analysis reports, memos, photos, field observations and general site maintenance requirements. Data from various field note sources (i.e. ArcGIS, fieldmaps, Iauditor and Fulcrum) can be brought into the visualisation system for ease of access and asset management. Electronic field note apps are used on mobile devices so that data can be recorded in the field and synced directly to the system.

We have also added value to the data repository by incorporating other technologies into the integrated system and visualisation interface. These include aerial survey overlays, weather monitoring, soil moisture sensors, camera imagery and operational data – and we are always working with our client to ensure that visualisations are intuitive and easy to interpret.

The visualisation interface provides real-time and trend data for users, and can hone in on individual sensors anywhere across the facility. Faults can be analysed onsite using analysis tools – and offsite using available data trends.

We’ve also worked with our client to provide a secure data ingress pathway for remote equipment, and we’re continuing work on integrating the new system with existing traditional and emerging SCADA systems.

Throughout the long evolution of this monitoring journey, we have continually added new innovations to best serve our client’s needs – and are always looking for new ways to deliver effectively.

Every system needs continuous improvement

The existing system has brought significant benefits to our client’s ability to analyse and visualise the facility’s data. Yet technologies continue to improve and evolve at speed. For our clients, we are now using OSI Pi and Pi-Vision as a primary integration and visualisation tool, and have developed a proof-of-concept for delivering the capabilities of the current system using OSI Pi and Pi-Vision. This will allow greater flexibility to bring on-site data into a single visualisation system – agnostic of the historical databases currently in use.

With the pace of technological advances likely to accelerate, clients and consultants should all stay attuned to new monitoring developments and alert to possibilities for improving their system’s functionality and integration with a broad range of sensors and control systems.

With the right data at the right time coupled with meaningful analysis and user-friendly visualisation, every tailings facility’s management should be better able to make earlier and more informed decisions to reduce risk.

To find out more about Entura’s data and water management solutions, contact Phillip Ellerton.

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India and Australia can support each other’s clean energy journeys

The relationship between India and Australia goes far beyond our nations’ mutual love of cricket. We have deep people-to-people connections that have been formed over generations. At the beginning of the 20^th century, around 7000 people of Indian descent lived in Australia. Now, Indian-born Australians number more than 750,000 – a number that has doubled over the last decade and continues to grow.

It’s natural that our two countries should have a strong relationship across many domains. We have strong strategic and political ties, and our economic engagement opportunities are massive. This will be strengthened even further with the Australia-India Economic Cooperation and Trade Agreement.

In a sign of the deepening India–Australia relationship, in 2023 Australia’s Prime Minister Anthony Albanese and India’s Prime Minister Narendra Modi have shared senior bilateral visits both in India and in Australia. One of the major themes in these meetings has been the potential for the two nations to support each other’s journeys towards a clean energy transition and net zero targets.

Building clean energy connections

I’ve been privileged to be involved in furthering the Australia–India relationship as a member of the Australian Senior Business Delegation to India and a subsequent Roundtable with business leaders in Sydney. During these meetings, I spoke about the potential our nations have, despite our radically different sizes, to work together to overcome challenges in our renewable energy sectors. I put forward the idea of a joint renewable energy council, which was well received. I am now on the Australia India CEO Forum’s Energy, Resources, Net Zero and Critical Minerals Joint Working Group, which had its first meeting this month. And this week, Entura has welcomed a visit from the High Commissioner of India to Australia, Manpreet Vohra, at our Hobart offices.

These opportunities have been realised after forging relationships with government officials across Australia and India over many years – and having maintained an Entura presence in India for more than 17 years with our highly skilled team based in New Delhi. Entura is a leader in the renewable energy industry and at present is the only Australia-based, government-owned business operating in the sector in India.

Entura is an excellent example of how Australia and India can support each other towards our clean energy goals. With India committed to net zero by 2070 and with 60% of its current energy production coming from coal, there are huge decarbonisation moves underway, including plans for 500 GW of renewable energy by 2030. Renewable electricity is growing at a faster rate in India than in any other major economy. Electricity demand is expected to double over the next decade and the share of wind, solar, hydropower, batteries and pumped hydro will lift as a proportion of the mix.

For Entura’s clients in India, we bring deep hydropower and pumped hydro capability and significant expertise in hybrid renewables systems, integrating distributed energy resources, resolving transmission challenges, and delivering bespoke, tailored training and capacity building through the Entura clean energy and water institute, with a particular focus on dam safety. For our projects in Australia, our India team brings a wealth of talent and a boost to capacity. They also have the local knowledge and connections that go a long way towards our success in clean energy and water projects across South Asia and South-east Asia.

Building on Entura’s long engagement with India, and from my involvement with the International Hydropower Association, I see the following areas as particularly important for our nations to focus on for mutual benefit in the energy transition.

1 Diversifying supply chains in critical minerals and renewable energy technologies

As both countries strive to achieve ambitious renewable energy targets, we will need to develop more diverse and resilient supply chains. The extraction and processing of critical minerals will be an essential area for cooperation. Mechanisms such as The India–Australia Critical Minerals Research Partnership and India–Australia Critical Minerals Investment Partnership will integrate Indian scientific, industry and government partners with CSIRO’s developing Critical Energy Metals Mission. This holds great potential to strengthen supply chains, add value to Australian exports, and support the commercialisation of critical minerals technology.

Another crucial factor in the success of Australia’s renewables, green hydrogen and green steel ambitions is the availability of components such as solar PV panels, batteries, electrolysers and electrical componentry. India is a powerhouse of manufacturing capability and could become a major supplier of these essentials to support Australia’s build-out of renewables. The announced joint taskforce on solar and the initiatives underway to collaborate on green hydrogen and green steel are encouraging developments.

2 People power and knowledge-sharing

Developing a skilled workforce, ready to take up the jobs of the future, is a make-or-break factor for the clean energy transition. As Entura has experienced, India has a deep pool of technical talent in renewable energy and a rising skilled workforce. To put it in context, India has over 1000 universities and some estimates suggest that these institutions are producing more than 1 million engineering graduates per year.

Australian businesses such as Entura benefit from having access to this talent – especially facing escalating skills and resources shortages in Australia – and we’ve found that with the right tools, methods and attitudes, our people across Australia and India can work seamlessly together in integrated teams, leveraging each other’s strengths on projects throughout the Indo-Pacific. Our India team adds diversity and capacity to our business – with the added bonus of optimising project delivery across time zones. We also benefit from the ability to build greater understanding of local conditions and regulations in India, and to forge strong networks and partnerships in the region.

Over the years, we’ve identified that despite the size of the potential renewable energy workforce, India still seeks greater skills development and expertise in hydropower, dam safety and the integration of renewable energy technologies. Entura’s clean energy and water institute (ECEWI) is a model of how long-term experience of developing and maintaining renewable energy assets, which we’ve gained through Tasmania’s century-long hydropower journey, can be shared across the world to build skills and capacity that extend far beyond the theoretical or academic.

Through ECEWI, we’ve delivered successful exchange programs, training workshops, and capacity-building initiatives in India, including dam safety training for India’s Central Water Commission as part of its Dam Rehabilitation and Improvement Project (DRIP) – and we’re now supporting the South Asia Regional Infrastructure Connectivity Framework (an initiative of the Australian Department of Foreign Affairs and Trade) by providing capability development on dam safety and cross-border power markets.

3 Innovation and best practice

There is enormous scope for Australia and India to work together to drive innovation in clean energy technologies and to share best practices and solutions. Many initiatives are already underway, drawing on Australia’s advanced technical expertise in solar and wind farms, energy storage solutions, and grid integration projects. For example, Entura is applying experience in India that we’ve gained in world-leading projects in Australia – such as our understanding of offgrid hybrid renewables systems gained from powering the Bass Strait islands, and the work our teams have led to identify and progress the first new pumped hydropower opportunities in Australia for decades in Tasmania and in Queensland.

As developers conduct concept studies and seek to secure licences for renewable projects, sharing international expertise such as ours will be an advantage. We are already applying our pumped hydro screening processes to identify new opportunities in India, and looking at the potential for repurposing disused mine sites for new renewable energy projects, as we are doing at the former Kidston gold mine in Queensland. We’re also applying our knowledge of repowering existing wind and solar farms in the quest for economical and sustainable approaches to boost electricity generation.

This brings me to another key area in which Australia can help to support a ‘fair’ clean energy transition in India. Australia has some of the strongest environmental and social requirements for clean energy projects in the world, and we’ve learned a lot about sustainability along the way. Entura has long been an advocate for sustainable projects conducted with integrity. In fact, I’ve just returned from the International Hydropower Association’s world congress, which reinforced this theme, announcing a new Hydropower Sustainability Alliance and the Bali Statement of Powering Sustainable Growth. Businesses like Entura can foster a fairer clean energy transition in India by promoting high standards of sustainability in all the projects in which we participate and the training we deliver.

Working together on the three factors I’ve discussed here will help build greater success, resilience and sustainability in all areas of the renewable energy transition. Lowering emissions in the global energy sector is an enormous and daunting endeavour that can’t be solved without international collaboration. But we’re at a very exciting point in the journey. We look forward to continuing the close and mutually beneficial relationship between our nations. Accelerating the global clean energy transition is the most important legacy we can leave today’s communities, future generations, and this planet we all share.

About the author

Tammy Chu is the Managing Director of Entura, one of the world’s most experienced specialist power and water consulting firms. She is responsible for Entura’s business strategy, performance and services to clients, and is part of Hydro Tasmania’s Leadership Group. As a civil engineer, Tammy specialised in the design and construction of mini-hydro and hydropower systems, project management, hydropower investigations, prefeasibility and feasibility studies, environmental assessments and approvals, resource investigations and resource water management. Tammy is a member of the Board of the International Hydropower Association. She was the first female and now past president of the Tasmanian Division of Engineers Australia, and was an Engineers Australia National Congress representative.

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