Join us as we formally welcome our international guests and officials. This pre-summit gathering offers a valuable opportunity to connect with fellow speakers, delegates, and dignitaries from across Oceania. Guests will also hear from a selection of distinguished speakers, setting the tone for the summit ahead.

Your essential snapshot of the region’s renewable energy transition

Kickstart the 2026 Summit with a fast, insight packed tour of how Australia, New Zealand and the Pacific are evolving in one of the most dynamic years yet for renewable power.

Brian Moore returns with an updated regional outlook – covering rising electricity demand driven in part by New Zealand’s surge in data centre investment, Australia’s rapid scaleup of solar plus storage through the latest CIS awards, and the Pacific’s accelerating shift toward microgrids and diesel displacement programmes.

• market momentum across Oceania – how structural differences are shaping investment, affordability, and deployment speed
• wind and solar in 2026 – updated resource trends and insights from major planning processes, including Australia’s Draft 2026 ISP and New Zealand’s future grid work
• update on a rapidly expanding project pipeline

How New Zealand and Pacific Island nations can accelerate renewable energy deployment, build climate-resilient power systems, and collaborate on investment, technology transfer, and workforce capability in a rapidly evolving energy landscape.

• foreign aid and the donor landscape
• NZ’s commitment to Pacific partnerships in climate adaptation and energy development
• diesel fuel dependency and geopolitical considerations in the Pacific
• opening markets, attracting private investment and Independent Power Producers, all while ensuring affordability

For decades, the Chatham Islands operated a 100% diesel-based electricity system. With the completion of the Point Durham wind project - three second-hand 225 kW Vestas turbines supported by 576 kW BESS - the islands have rapidly transitioned to a renewable share exceeding 65%.

• integrating variable renewables with storage and intelligent load management
• next steps, including smarter energy management approaches such as new hot water load control using cold stores as batteries to absorb surplus renewable generation and reduce peak demand
• lessons for other small island grids and remote communities
• scaling renewables in places with severe logistics, limited budgets, and little room for failure
• lessons on which suppliers, engineers and contractors to use

Households are moving beyond 5–6 kW rooftop PV and 10–15 kW three-phase inverters, hybrid systems, and larger batteries are becoming mainstream choices - driven by electrification (EVs, heat pumps), tariff reform, subsidies, and falling storage costs. In parallel, regulators are enabling flexible trading and multiple service providers at a single premise.

The upside is huge: system-level modelling reaffirms firmed renewables + storage as the least-cost path; deeper evening peak shaving and ramp mitigation becomes the norm.

But integration challenges intensify as households store and shift more energy.

• what are the key challenges for grid operators
• market design that unlocks value
• how to fast-track connections while protecting consumers and keeping wholesale/FCAS markets stable
• planning for the 2030s: With battery capex curves moving lower, expect greater evening discharge and shoulder-to-peak shifting from homes/VPPs; what this means for feeder hosting capacity, minimum-demand management, and retail/network tariff reform

As Lodestone Energy moves from its early utility‑scale solar projects into a full national portfolio, CEO Gary Holden reflects on the hard‑won lessons from the past several years - and what he’d change if starting again. This session offers an unvarnished view of what it really takes to scale solar in New Zealand, from navigating lines‑company relationships to building world‑firsts in retail innovation.

• lines company/EDB partnerships - what works
• regulatory barriers and where real improvements are needed
• working with (and around) incumbents
• our world-firsts in retailing solar and 'virtual rooftop' contracts
• product developments coming out of China

Utility-scale solar is undergoing a period of rapid technical advancement, driven largely by innovation and manufacturing scale in China. Improvements in cell architecture, module design, balance-of-system optimisation and hybridisation with storage are materially changing project performance, reducing LCOE, and reshaping how solar integrates into increasingly constrained grids.

This discussion will focus on how innovations such as n-type TOPCon and heterojunction (HJT) cells, bifacial modules with high rear-side gain, and 210mm large-format wafers are driving higher energy yields, improved degradation profiles and better performance under diverse operating conditions.

• the performance characteristics of bifacial+tracker configurations, particularly in high-albedo and coastal environments
• advances in single-axis tracking systems, including wind-stow strategies and structural resilience for cyclonic regions
• integration of DC-coupled and AC-coupled storage systems to provide firming, frequency response and grid support services
• design considerations for weak grids and island systems, including voltage stability, ramp-rate control and inverter-based grid-forming capabilities
• global pricing dynamics and supply chain resilience
• bankability considerations, including warranties, performance guarantees and long-term degradation assumptions

Australia and New Zealand are overhauling network regulation to unlock electrification, distributed energy resources (DER/CER), and major grid builds – all being attempted with a sharp view on pricing and the consumer. Both have different systems in place with similar objectives in mind. In this panel we take a look at some of the key considerations and share learnings from either side.

DPP4 price/quality path (NZ) vs incentive-based revenue scheme (Australia): Should price‑quality paths or incentive schemes more explicitly reward hosting capacity and flexible connection enablement?

• network innovation: when should regulators carve out funding for innovation
• ring-fencing and contestability
• what is the regulator’s role in lifting constraints vs simply getting out of the way
• the challenge posed by the World Energy Council's trilemma index and the role of regulators in achieving this

Across Oceania, the renewable energy project pipeline is growing rapidly but moving projects from concept to commissioning remains a persistent challenge. Complex permitting processes, limited grid capacity, fragmented institutional responsibilities and constrained local delivery capability can all slow progress, particularly in small island and emerging markets.

• key stages in the project development lifecycle from feasibility and resource assessment through to detailed design, procurement and construction
• how to navigate pre-development constraints, including site identification, environmental approvals, land access and stakeholder engagement in Pacific jurisdictions
• engineering and design considerations for island grids and constrained networks, including system stability, integration of high penetrations of solar and storage, and resilience to extreme weather events
• approaches to improving bankability, including risk allocation, technical due diligence, and aligning project design with lender requirements and utility expectations

This session will share frontline insights from Vanuatu, where cyclones, flooding, and seismic events regularly test electricity infrastructure. Hear from the chief executive of the primary utility company UNELCO Engie about successful initiatives, learnings and advice for utilities across Oceania.

• network resilience: hardening assets and designing systems for extreme events
• role of renewables: using solar and battery systems to maintain supply during outages
• rapid restoration: improving emergency response and recovery practices
• community and workforce readiness: building capability before disasters strike
• regional collaboration: sharing knowledge and resources across Pacific utilities

EFL’s network spans thousands of kilometres and serves more than 220,000 customers. As Fiji moves toward its ambitious target of 99% renewable electricity by 2030, EFL’s role has never been more critical.

The company’s generation portfolio is already dominated by hydropower, complemented by wind and thermal assets, but the next decade will see transformative investments in solar, battery storage, and grid modernisation. These developments are designed to strengthen resilience, reduce reliance on imported fuels, and deliver clean energy to even the most remote communities.

EFL’s roadmap includes major capital projects in 2026 and 2027, such as new hydro schemes, large-scale solar farms, and advanced transmission upgrades. At the same time, initiatives like rural grid extensions and mini-grid deployments are bringing electricity to villages that have never had reliable power before—unlocking opportunities for education, healthcare, and local enterprise.

This session will explore how EFL is balancing technical innovation, financial partnerships, and social impact to create a sustainable energy future for Fiji and the wider Oceania region.

• generation mix & future plans: hydropower, solar, wind, and battery storage initiatives
• big ticket projects: hydro expansions, grid-scale solar, and transmission upgrades in 2026–2027. Project Deep Dive: 165 MW solar + BESS
• financing and partnerships: how EFL collaborates with ADB, JICA, and global partner
• remote community electrification: mini-grids, rural grid extensions, and social impact
• path to 99% renewables by 2030: strategic roadmap and challenges

Regulators in both Australia and New Zealand have completed major electricity market reviews, and the implementation burden now shifts squarely to industry. The Nelson Review’s reforms - such as the Electricity Services Entry Mechanism and improved market‑making and transparency - aim to catalyse firmed‑renewable investment as coal exits the NEM. Meanwhile, the Frontier Review’s recommendations are driving strengthened security‑of‑supply oversight, expanded Transpower and EA responsibilities, and better investment signals amid concerns about insufficient firm capacity. But uncertainties remain around delivery.

• the current generation pipeline: firming vs new generation. Enter the gentailer
• who is handling oversight of deliverables and could another phase of work emerge?
• steps taken by the regulators

TIDES - Transforming Island Development through Electrification and Sustainability – is an innovative blended finance initiative designed to unlock private sector investment in renewable energy across Pacific island countries.

The platform is targeting approximately USD $100 million in total capital mobilisation, combining public and private finance into a single investment vehicle. Anchor funding has been provided by the governments of the United Kingdom and New Zealand.

• the current status of the TIDES platform, including priority markets, project pipeline and investment structures
• how blended finance mechanisms are being used to de-risk projects and crowd-in private capital, particularly for independent power producers (IPPs)
• priority markets and pipeline development across Fiji, Tonga, Samoa, Cook Islands, Vanuatu and Solomon Islands, where TIDES is actively targeting investment opportunities
• early examples of the types of projects being supported, including utility-scale solar, commercial & industrial installations, and mini-grid electrification, typically in the $0.5m to $10m range per project

As Pacific power systems move toward higher shares of renewable energy and greater private sector participation, effective regulation has become one of the critical enablers of investment. Clear rules, credible institutions, consistent standards and transparent processes are essential to reducing risk for independent power producers (IPPs) while safeguarding affordability, reliability and consumer outcomes.

OPERA - the Pacific energy regulators support programme - is strengthening regulatory capability across the region to support the energy transition and facilitate the entry of IPPs:

• the role of independent, capable regulators in enabling renewable energy investment and private sector participation
• key regulatory frameworks and standards being applied across the Pacific to support IPPs, including tariff-setting, licensing, power purchase agreements and technical standards
• how regulators can help de‑risk IPP entry while maintaining system integrity and consumer protection
• lessons learned from Pacific jurisdictions at different stages of regulatory maturity, and what still needs to be strengthened

As renewable energy penetration accelerates, the challenge is no longer just adding generation, it is coordinating where, when and how projects connect to the grid. Poorly sequenced development risks network congestion, rising connection costs and delayed projects, while well‑coordinated planning can unlock scale, reduce system costs and improve investment certainty.

In this session we explore how jurisdictions can move from fragmented project-by-project development toward co-ordinated, system-level planning and delivery.

• the role of Renewable Energy Zones (REZs) in aligning generation development with transmission investment, and lessons from the NSW REZ model in sequencing capacity and procurement
• whether and how transmission delivery should be contestable, including the trade-offs between centralised planning and competitive delivery frameworks
• the evolution of grid access models, including cluster and batch connection approaches, and how these can reduce connection risk, streamline approvals and better allocate network capacity
• technical and commercial considerations in integrating storage alongside generation, including how different mixes of solar, wind and storage affect system stability, utilisation of network assets, and overall project economics
• the importance of co-ordination between system planners, network operators, governments and developers to avoid bottlenecks and ensure efficient build-out at scale

Palau’s electricity system remains largely dependent on imported diesel, historically supplying over 97% of generation, but is now undergoing a significant transition toward solar‑plus‑storage. A major milestone has been the commissioning of Palau’s first utility‑scale solar and battery project in 2023, capable of supplying around 20% of national electricity demand, supported by ongoing grid upgrades to enable higher renewable penetration. The system is evolving with investment focused on improving grid stability and integrating intermittent generation across the main island grid.

Solomon Power is progressing a coordinated shift toward solar, storage, and hydro. A key recent addition is the rollout of provincial solar hybrid systems, including a 3.27 MW grid‑connected solar programme.

These solar developments are being complemented by a growing battery storage programme, with multiple projects underway:

• 9 MW / 24 MWh grid‑scale battery storage (paired with ~2.5 MW solar) to support the Honiara system and reduce reliance on diesel peaking plant
• a flagship utility‑scale BESS in Honiara – expected to be one of the largest grid‑connected batteries in the Pacific
• Tina River Hydropower Project (15 MW), the country’s first utility‑scale hydro scheme
• expansion of hybrid mini‑grids across provincial centres
  

The Electricity Authority’s work to evolve wholesale market design and operations is as important as ever, with baseload thermal decommissioning and grid-scale solar and batteries attracting record investment. The Authority’s view of the future generation system involves hydro playing an even more important storage and firming role and doing less as the baseload workhorse.

• what we are seeing in terms of the transition to the very high renewables future
• how wholesale prices are tracking seven years after the sudden loss of Pohokura and with gas production continuing to disappoint
• how the system could manage a “dry year” and what will provide long-duration firming
• how to get through capacity crunches and ensure system security in this new world
• what all of this means for the cost of retail energy for households and businesses, with electrification also expected to increase demand significantly.

Samoa is rapidly advancing towards its national target of 100% renewable electricity by 2025, with solar and hydropower already supplying more than 60% of generation. Recent investment in solar farms, battery storage, and supporting grid upgrades—backed by international partners—has strengthened energy security and reduced reliance on imported diesel, while upcoming projects aim to further diversify the renewable mix.

Floating photovoltaics (FPV) - especially nearshore FPV engineered for coastal conditions - offer a practical, scalable pathway to accelerate renewable energy adoption without competing for limited land. The Pacific islands represent a prime opportunity for this technology.

• location factors: using sheltered waters such as lagoons, port basins, bays, and industrial waterfronts
• targeting ports and island grids: many ports sit beside calm, underused waters that could host nearshore FPV, as for small island grids
• how marine‑grade FPV engineering has matured to withstand real-world coastal wave and wind environments
• cost dynamics and why nearshore FPV is now commercially viable
• enabling policy and permitting frameworks
• case studies and practical cost-benefit overview

• considerations around ground conditions and Geotech
• advances in GPS‑guided piling rigs and automated depth/torque monitoring
• trade‑offs between C‑section, H‑section, screw, and driven piles
• how piling strategy affects EPC timelines, capex, and labour deployment

Focusing on real‑world pathways rather than theory, the discussion will explore how projects move from concept to funding, and how stakeholders can best position themselves to access international support.

• how to engage: navigating World Bank processes and entry points for utilities, IPPs, and
  governments
• funding options: grants, concessional finance, guarantees, and blended finance structures
• project readiness: what makes a project “bankable” in the Pacific context
• working with partners: aligning with governments, regulators, and development partners
• common challenges: overcoming barriers to delivery in small and remote markets
  

This roundtable will explore the growing link between the energy transition and financial resilience across Pacific utilities and governments, with a focus onlessons from the recent regional fuel crisis.

• fuel price shocks: how recent volatility has impacted utility balance sheets and government finances
• utility financial health: implications for tariffs, cost recovery models and reserves
• government budgets: impacts on fiscal planning, public expenditure, national debt and foreign exchange
• reducing exposure: the role of renewables in derisking fuel import costs and stabilising the cost base
• investment trade-offs: managing upfront capital costs versus long term savings
• regional lessons: practical insights from Pacific utilities navigating the transition under fuel price changes

Advanced datacentres are no longer “just another large load”. AI training cycles, ultra‑tight uptime SLAs and behind‑the‑meter transfer logic make these facilities fast, programmable and sometimes invisible to operators. They exhibit step changes in demand, rapid ramping, and have the ability to drop or shift hundreds of megawatts within seconds. That challenges forecasting, frequency control and reserve sufficiency, and it forces new thinking in connection policy, commercial frameworks and system operations. New Zealand, Australia and Fiji are all experiencing growth in datacentres.

• the Australian regulatory direction with emerging large loads. Dealing with ramp-rates
• the Irish example around dispatchable generation, storage, “bring‑your‑own‑generation” and renewable power requirements
• paying for connectivity and upgrades. Where to locate them?
• PPAs with datacentres

Explore how flexible electricity - where consumers adjust when and how much energy they use in response to system conditions - can accelerate resilience and affordability across Oceania by improving visibility, measurement, and commercial viability. Drawing on Ara Ake’s research, platform development, and National Flex Discovery Fund insights, this session examines pathways to scale flexible demand, strengthen DER integration, and enable supportive regulatory settings.

• how shared platforms like FlexViz improve visibility of flexible resources and open access to flexibility markets.
• the role of accurate baselining, commercialisation support, and regulatory tools in enabling flexible load, DER integration, and market participation.
• opportunities for Pacific Island grids to boost resilience and defer costly upgrades through distributed flexibility and community‑driven DER solutions

As renewable penetration accelerates across Pacific Island power systems, diesel remains a critical—if increasingly complex—part of the energy mix. With demand diminishing for power diesel, poorly managed diesel supply chains can erode the reliability gains delivered by renewables, undermine public and investor confidence, and slow the pace of transition.

In 2026, global fuel price volatility and heightened geopolitical risk have sharpened the challenge. Disruptions to supply routes, aging fuels infrastructure, sharply rising and volatile procurement costs, and tighter credit conditions are testing the resilience of diesel strategies across the region. Yet diesel will still be required for decades to underpin system stability, manage variability, and respond to extreme weather and outages.

• managing diesel price volatility alongside growing renewable generation
• security of supply risks and contingency planning for island systems
• improving fuel demand forecasting as load profiles change
• procurement strategies and contract structures in uncertain markets
• determining adequate reserve levels without over capitalising inventory
• aligning diesel strategies with investor confidence and long term transition plans

With Eku Energy’s experience investing, developing and operating utility scale BESS, this topic will explore how the evolving merchant revenue stack, alongside growing offtaker demand, is driving innovation in contract structures to support BESS investment.

The Electricity Authority has been advancing a programme of work to improve the consistency, transparency, and performance of distributed generation conections, with a focus on reducing friction for applicants while ensuring networks can manage increasing two-way power flows.where progress is being
made, where gaps remain, and what COP29/30 outcomes mean as we head to COP31 in 2026

• progress on improving connection processes, timelines, and information transparency for DG applicants
• challenges faced by EDBs in managing hosting capacity, voltage constraints, and localised congestion

Pacific island nations have some of the world’s most ambitious renewable energy targets. Yet across the region, renewable energy uptake continues to fall short of national objectives — not because of limited resources or political ambition, but due to structural gaps in grid readiness, planning transparency, implementation capability, and investment delivery systems.

Drawing on the findings of the Framework for Energy Security and Resilience in the Pacific (FESRIP) Mid-Term Review and the FESRIP 2.0 framework endorsed at PRETMM6 in May 2026, this session explores the systemic shift now required across Pacific and island energy systems.

• why grid readiness - not generation potential - has become the primary constraint on renewable integration
• the importance of transparent, “glass-box” planning methodologies and open-source modelling approaches in building bankable project pipelines
• the role of integrated planning, institutional strengthening, and data-driven decision-making in enabling resilient island power systems
• transferable lessons for Oceania’s broader island and coastal energy systems

As renewable penetration accelerates across Oceania, utility‑scale batteries are moving from early‑stage innovation to core grid infrastructure. In 2026, the commercial landscape for storage is being driven by sharper wholesale market volatility, tightening grid‑firming requirements, and the emergence of long‑duration storage as a serious planning consideration.

This year, we hear from Rachel Rundle of Eku Energy, a developer actively progressing large-scale battery projects across Australia and New Zealand. Rachel will unpack how the investment case for batteries has evolved and where the most compelling markets now lie.

• updated market rules across Australia’s NEM, New Zealand’s wholesale market and what they mean for revenue stacking and project bankability
• seasonal drivers: comparing Australia’s summer peaks with New Zealand’s dry season constraints
• short‑duration vs long‑duration storage in 2026: understanding how the business case is shifting as multi‑hour and long‑duration technologies start to enter the market

Across the Pacific, governments are grappling with how to expand generation capacity, accelerate renewable uptake, and attract independent power producers (IPPs) into systems long dominated by vertically integrated, state-owned utilities. While the potential for IPPs is significant - particularly in solar, storage and hybrid mini-grid applications - the investment environment remains uneven, and pre-development work is often under-resourced or left entirely to utilities with limited balance sheets. This panel examines what a workable IPP model looks like for Pacific energy systems:

• the respective roles of governments and incumbents in de-risking entry, and how market structures can evolve from utility-led procurement toward more open, competitive participation
• how many IPPs are operating in the Pacific and what types of projects are proving bankable
• pre-development challenges: who should undertake resource studies, network studies, site identification, permitting and early negotiation—utilities, government agencies, or blended models?

Further panelists under invitation

Contact Energy will provide a focused snapshot of its wind and solar development programme, including current projects under construction, sites progressing through consent and design, and how these fit into Contact’s broader decarbonisation strategy. A fast, forward‑looking update on where Contact is placing its renewable investment focus for the coming years.

Meridian’s multi‑year transformation initiative focused on using data, automation, and advanced analytics to optimise the performance, reliability, and flexibility of its hydro and wind generation fleet.

Genesis will outline progress across its solar programme and firming investments including solar farms: Edgecumbe 116 MW, Leeston 57 MW, Foxton 187 MW and Rangiriri 230 MW. These projects sit alongside construction of a 100 MW / 200 MWh grid‑scale battery at Huntly, under the company’s Gen35 strategy.

Small markets, grid constraints, and state‑owned utility dominance continue to limit private sector participation in the Pacific. A central focus of this session is practical advice for Pacific Island governments and regulators on establishing market settings that encourage IPPs.

• de-risking tools for IPP projects where governments have limitatioins: donor‑backed partial risk guarantees, letters of credit, direct lending
• tender advice
• regulatory sandboxing to test new models
• land access, permitting, network studies and tariff structures to reduce transaction friction
• directing and empowering incumbent state‑owned utilities to participate constructively in enabling new generation

Mint has assembled a 4 GW portfolio of early‑stage wind, solar and storage projects across Australia. Hear latest updates on these projects from this fast-scaling developer.

What is the big-picture climate trajectory across Oceania in 2026? Regulatory, policy, and market settings across the region are adapting to accelerate decarbonisation - while attempting to maintain secure, affordable energy systems.

• where progress is being made, where gaps remain, and what COP29/30 outcomes mean as we head to COP31 in 2026
• the role of regulation in managing grid transition risks
• how regulators can support small-system reliability, market design for microgrids, and cross-border knowledge transfer to assist island utilities facing extreme climate and economic risk.
• Australasian climate finance for the Pacific