Energy industry trends
Invest earlier in emerging technologies and processes, foster collaborative partnerships, and manage the energy transition with interactive, shareable roadmaps.
Energy industry trends 2026+
Renewables reached 49% of global installed power capacity in 2025 and accounted for 85.6% of all capacity added that year. Battery storage additions rose roughly 40% to almost 110 GW. Building clean generation is now the solved part of the problem.
Connecting it is not. Around 1,700 GW of renewable projects sat in European connection queues across 16 countries, more than six times Germany's total installed generation capacity, while ENTSO-E reports over half the transmission projects needed by 2030 still awaiting permits.
Curtailment cost Europe roughly 8.9 billion euros against 72 TWh of mostly renewable power. The Council puts the European grid investment gap at 1.2 trillion euros by 2040. Permitting throughput, transformer and cable lead times, and grid-forming inverter compliance now decide delivery schedules.
The second shift is that digital capability and exposure have become the same asset. DERMS and ADMS rollouts, IoT pipeline monitoring, V2G, and smart metering deliver the flexibility the system requires and extend the attack surface into the control layer. CISA, NSA, and FBI have formally identified PRC state-sponsored pre-positioning on IT and OT networks, which describes a patient, resident adversary rather than an opportunistic one.
The third shift is that compliance replaced ambition. CBAM entered its definitive regime on 1 January 2026. NIS2 and the CER Directive are in force with penalties attached, and the EU Methane Regulation's import provisions reach non-EU producers serving European markets. Deadlines now bind, and the gap between announced capacity and operational capacity has never carried more cost.
This report covers upstream, midstream, and downstream. For each segment, it names the trend developments that change capital allocation, compliance exposure, and portfolio decisions over the next ten years.
Want to explore any trend details?
Interact with the ITONICS Energy Industry Trend Radar.
New and declining trends for 2026
The trends tracked in this year's report reflect a significant restructuring of the landscape. 35 trends were excluded. 36 new trends were added, sharpening the focus on integrated utilities, grid and T&D, oil and gas majors, and renewables/storage/hydrogen.
What was removed
We excluded 35 trends because of consensus-saturated themes that repeat without adding strategic signal, and overlapping midstream trends subsumed by more precise entries.
Examples include: Political Pressure to Phase Out Fossil Fuels, Growing Public Demand for Clean Energy Products, Next-Generation Chips, and a cluster of social equity and community relations trends.
What was added
New trends introduced this cycle include:
-
Grid-Forming Inverter Proliferation — as inverter-based resources displace synchronous generators, grid stability mechanics are being rewritten
-
Dynamic Line Rating and Grid-Enhancing Technologies — unlocking 20–40% of stranded transmission capacity without new wire
-
Long-Duration Energy Storage Scale-Up — iron-air, flow batteries, and thermal storage advancing toward commercial deployment
-
Green Hydrogen Electrolyser Cost Reduction and Scale-Up — PEM and alkaline costs still 3–5× above grey hydrogen parity, but the trajectory is the story
-
Carbon Border Adjustment Mechanism and Trade-Embedded Emissions — CBAM in full implementation from 2026, reshaping refinery and midstream competitiveness globally
-
Biodiversity Net Gain Requirements for Energy Projects — moving beyond "do no harm" into mandatory net positive obligations for project permitting
-
Workforce Transition and Skills Gap in the Energy Sector — the energy transition is simultaneously shrinking fossil fuel employment and creating acute shortages in grid, storage, and hydrogen roles
What was upgraded
Cyberattacks on energy infrastructure emerged as the most materially upgraded trend. The sector now ranks fourth most targeted, accounting for roughly 10% of all incidents. CISA, NSA, and FBI formally identified PRC state-sponsored actors pre-positioning on IT and OT networks.
DERMS and ADMS deployments, IoT pipeline monitoring, V2G integration, and smart metering have expanded the attack surface in step with the capability they deliver. The sector's existential vulnerability is precisely what drives its value. NIS2 is in force, the CER Directive classifies critical operators, and IEC 62443 is becoming the certification benchmark for integrators and manufacturers, with the Cyber Resilience Act extending obligations into supply chain security and software bills of materials.
Humanoid utility co-bots were retained and upgraded. The technology advanced into TRL 6 to 7 for defined task categories, cost curves are falling quickly, and pilot programmes are active across European grid operators and majors. Material commercial impact is expected from 2028, reinforced by field workforce supply emerging as a hard delivery constraint.
Grid modernization was elevated to reflect a new reality: network infrastructure, not generation capacity, is the primary bottleneck to transition delivery. The Council puts the European grid investment gap at 1.2 trillion euros by 2040. Record interconnection queues, data centre load growth, and mandatory grid-forming inverter compliance repositioned this trend from enabler to constraint. The European Grids Package reached a Council general approach on 26 June 2026 and now sits in trilogue
All changes reflect an energy sector where digitalization's benefits are inseparable from their security costs, where the regulatory baseline has shifted from targets to binding implementation (EU Methane Regulation, CBAM, Industrial Carbon Management Strategy), and where the distinction between announced capacity and operational capacity has never mattered more.
Upstream - Exploration & Production
The upstream segment sits at a structural inflection point where technology, regulation, and geopolitics are compressing conventional economics while opening new competitive frontiers.
The sector is past early AI adoption. Generative AI is embedded in subsurface interpretation, cutting seismic cycle times by 40 to 60% at leading operators. Autonomous drilling is commercially deployed across major offshore basins, reducing non-productive time by 15 to 25%. Digital twins synchronised with live production data are the operational standard. Satellite methane detection rewrote the accountability landscape: material emissions events are visible to regulators and investors in near-real time, making voluntary self-reporting insufficient and accelerating mandatory MRV compliance.
Consolidation anchored by ExxonMobil/Pioneer, Chevron/Hess, and Diamondback/Endeavor favours large operators with the scale to amortise AI investment, absorb compliance costs, and fund drilling electrification. Sub-scale independents carry structural disadvantage and form the primary M&A target pool through 2030. Stranded asset risk is intensifying for high-cost, high-carbon positions as EU ETS pricing, CBAM, and ESG-linked financing tighten the case for frontier basin development.
The regulatory baseline moved from ambition to obligation. The EU Methane Regulation imposes binding MRV duties across the upstream value chain, with import provisions extending compliance pressure to non-EU producers serving European markets. Biodiversity net gain requirements, stricter EIA standards, and expanding Arctic moratoriums are lengthening permitting timelines. Energy security support has broadened beyond hydrocarbons into critical minerals, grid resilience, and domestic clean energy manufacturing.
The sector is bifurcating. Operators investing in low-carbon practice, AI efficiency, and transition-aligned portfolios are securing preferential capital, offtake, and licences. The rest face compounding stranded asset and regulatory risk through the late 2020s.
In the following, we highlight the three most critical upstream trend developments. Download the complete list of all trends affecting the energy industry 2026+.
Satellite-Based Methane Detection and Regulatory Enforcement
Current Situation: Methane drives roughly 30% of current global warming, and oil and gas is the largest industrial source. Constellations from GHGSat, MethaneSAT, and Copernicus deliver near-continuous facility-level monitoring, so material leaks from pipelines, compressor stations, and upstream sites are visible to regulators and investors within days. Several major operators have been publicly identified as significant emitters.
Expected Development: Resolution, revisit frequency, and attribution accuracy continue improving through the late 2020s. Satellite data combined with AI anomaly detection and ground-based monitoring creates multi-layer verification. The EU Methane Regulation's import provisions extend MRV obligations to non-EU suppliers, setting a de facto global standard. Methane intensity becomes embedded in ESG ratings, debt covenants, and offtake agreements.
Challenges: Cloud cover and atmospheric interference limit accuracy in tropical and high-latitude basins. Satellite detections require ground-truth corroboration before they can support formal enforcement, adding evidentiary complexity. Attribution is uncertain where multiple emission sources sit close together. Operators in jurisdictions with weaker monitoring infrastructure may lack the technical capacity to respond within regulatory timelines.
Time to Maximum Impact: 0-2 years
Potential Impact: Very High
STEEP Segment: Ecological
Stranded Asset Risk in Fossil Fuel Infrastructure
Current Situation: European refinery closures are accelerating under compressed margins, rising EU ETS compliance costs, and structural demand erosion in transport fuels. Coal retirements are running ahead of schedule in several member states. Financial institutions now apply carbon price stress-testing to energy asset valuations, and stranded asset risk is reflected directly in the cost of capital for fossil fuel projects.
Expected Development: Retirement accelerates through the late 2020s as carbon pricing escalates and heating and transport demand declines. European gas distribution networks face rising exposure as heat pump penetration grows, with some member states planning managed network retirement. Midstream assets divide between those repurposable for hydrogen or CO2 transport and those serving declining fossil demand.
Challenges: Pricing transition risk in assets with 20 to 40 year lives is difficult when pathway uncertainty is high. Political resistance to accelerated retirement is strong where infrastructure supports supply security or regional employment. Regulated utilities face disputes over whether stranded costs are recoverable from ratepayers. Decommissioning, remediation, and pension liabilities compete with transition capital.
Time to Maximum Impact: 2-4 years
Potential Impact: Very High
STEEP Segment: Economic
Subsurface Digitalization and AI in Upstream Exploration
Current Situation: Generative AI is in active deployment across seismic interpretation, reservoir characterisation, and well placement, with early adopters reporting 40 to 60% reductions in interpretation cycle times. The recent upstream M&A wave created larger data estates that strengthen the case for enterprise-scale analytics. Schlumberger's Delfi and Halliburton's iEnergy are displacing siloed desktop workflows with cloud-native platforms.
Expected Development: Generative AI moves from pilot to standard workflow at leading operators by 2027 to 2028. Predictive maintenance is expected to cut unplanned downtime by 20 to 30% across production facilities. The OSDU standard becomes the de facto interoperability layer, opening a third-party application ecosystem. Platforms transfer into geothermal site characterisation and CO2 storage assessment.
Challenges: Integrating AI with decades of heterogeneous legacy subsurface data remains a substantial technical barrier. Connecting subsurface platforms to cloud and AI infrastructure expands the attack surface for threats against critical infrastructure and proprietary exploration data. Geoscientists require explainability before trusting model outputs for high-stakes drilling decisions. Data governance across third-party tools raises ownership questions.
Time to Maximum Impact: 2-4 years
Potential Impact: High
STEEP Segment: Technological
Midstream - Transportation & Storage
The midstream segment is undergoing structural transformation, driven by the dual imperatives of decarbonising legacy fossil infrastructure and building the transport and storage networks the transition requires. Operators are managing stranded asset risk while competing for position in emerging hydrogen, CO₂, and LNG markets.
AI-driven predictive maintenance and IoT sensor networks moved from pilot to operational standard across major pipeline operators, cutting unplanned downtime by 20 to 30% and enabling continuous leak detection and repair compliance under the EU Methane Regulation. Satellite monitoring via MethaneSAT and GHGSat made independent near-real-time verification a reality, rendering self-reporting insufficient. HVDC backbone expansion is redefining the transmission layer, with over 100 GW of new interconnection capacity identified as necessary by 2030 for European renewable integration. Cable and converter station order books extending five to seven years are the binding near-term bottleneck.
The LNG market is shifting from 20-year oil-indexed take-or-pay contracts toward shorter-term spot arrangements, now above 35% of global trade. That raises volatility exposure, complicates project financing, and creates arbitrage value for operators with flexible trading and storage. EU ETS pricing and full CBAM implementation add a structural cost layer to gas-intensive operations, accelerating the case for pipeline electrification, hydrogen repurposing, and methane abatement. Assets capable of carrying hydrogen or CO₂ hold meaningful transition optionality. Assets serving declining fossil demand do not.
Regulation is tightening unambiguously. The EU Methane Regulation's import provisions extend MRV obligations to non-EU suppliers, creating a de facto global standard for anyone with European market exposure. Permitting remains the critical bottleneck despite RED III and FERC Order 2023, with cross-border hydrogen pipelines, CO₂ networks, and HVDC interconnectors facing the most complex multi-jurisdictional approvals. The CER and NIS2 Directives now mandate physical and cybersecurity standards across critical midstream assets.
The strategic divide is sharpening. Operators securing positions in hydrogen corridors, CO₂ hubs, and HVDC development while investing in digital compliance and methane abatement are building durable advantage. Those dependent on conventional throughput without a credible transition strategy face compounding regulatory, financial, and demand-side pressure through 2030.
In the following, we highlight the three most critical midstream trend developments. Download the complete list of all trends affecting the energy industry 2026+.
Transformer and Cable Supply Chain Constraints
Current Situation: Lead times for large power transformers above 100 MVA have extended to 3 to 5 years, up from 12 to 18 months before 2020. HVDC cable manufacturers including Prysmian and Nexans hold order books running 5 to 7 years. Manufacturing capacity is concentrated among a small number of European and Asian suppliers, creating both supply risk and geopolitical exposure for grid programmes.
Expected Development: Constraints persist through 2028 to 2030 as capacity additions lag transition-driven demand. New facilities backed by the EU Net-Zero Industry Act and the US Inflation Reduction Act require 3 to 5 years to reach full production. Design standardisation will improve throughput for standard ratings. Long-term framework agreements become standard practice, favouring early movers on delivery timelines.
Challenges: The bottleneck is structural and resists rapid resolution even with committed capital, because facility build-out itself takes 3 to 5 years. Shortages cascade across offshore wind connections, HVDC interconnectors, and substation upgrades, compounding queue and permitting delays. Price inflation since 2021 raises grid capital costs and can undermine the economics of projects awaiting connection.
Time to Maximum Impact: 0-2 years
Potential Impact: Very High
STEEP Segment: Economic
Interconnection Queue Reform and Cluster Studies
Current Situation: Interconnection queues have become the primary bottleneck to renewable deployment. The US FERC queue held over 2,700 GW of pending projects, with median waits above five years and withdrawal rates over 70%. FERC Order 2023 replaced serial studies with cluster-based processing, first-ready-first-served rules, and higher deposits. Great Britain is targeting a 90% reduction in connection wait times by 2030.
Expected Development: Cluster studies are expected to cut interconnection timelines by 2 to 3 years for projects entering the reformed process. European operators will adopt cluster frameworks as standard by 2030, supported by digital study platforms and AI-assisted network modelling. Developers that secure land, permits, and equipment before entering the queue will gain material delivery advantage.
Challenges: The existing backlog cannot be cleared quickly, and legacy serial-study projects will consume operator resources for years. Cluster cost allocation invites disputes and litigation between competing developers. System operators lack the engineering workforce to run studies at the required pace. Equipment lead times limit the real acceleration that queue reform alone can deliver.
Time to Maximum Impact: 2-4 years
Potential Impact: Very High
STEEP Segment: Political
Increasing Cyberattacks on Energy Infrastructure
Current Situation: CISA, NSA, and FBI have formally identified PRC state-sponsored actors pre-positioning on the IT and OT networks of energy operators, with intent to disrupt critical infrastructure in the event of geopolitical escalation. IT and OT convergence through grid digitalisation, DERMS and ADMS deployments, and IoT sensors across pipeline and generation assets has substantially expanded the available attack surface.
Expected Development: NIS2 transposition drives mandatory incident reporting, supply chain security assessment, and board-level accountability. IEC 62443 adoption broadens as regulators close exposed gaps. TSOs and DSOs are building security operations centres with dedicated OT monitoring. Distributed energy resources, V2G, and smart grid endpoints will enlarge the surface further, pushing zero-trust architecture and post-quantum cryptography migration.
Challenges: A persistent shortage of OT cybersecurity specialists constrains defensive build-out across utilities and grid operators. Grid communications equipment sourced from vendors tied to adversarial states creates procurement exposure that unwinds slowly. Patching safety-critical OT estates requires outage windows, so remediation is slow. State actors pursuing long-term pre-positioning present a threat that technical controls alone cannot fully mitigate.
Time to Maximum Impact: 2-4 years
Potential Impact: Very High
STEEP Segment: Technological
Downstream - Refinement & Distribution
The downstream segment is in the most visible phase of structural disruption across the energy value chain. EV penetration, tightening EU ETS costs, and binding SAF and HVO mandates are eroding conventional refining economics while creating policy-driven demand pools for low-carbon fuels.
The reconfiguration wave is well underway. Neste, TotalEnergies, ENI, and BP have committed capital to dedicated SAF and HVO units, with ReFuelEU Aviation requiring a 6% SAF blend by 2030 rising to 20% by 2035. Feedstock security across certified waste oils and agricultural residues is the primary competitive differentiator, with RED III certification constraining scale-up. E-fuels reach commercial relevance post-2028 as electrolyser costs decline, targeting aviation and shipping. Refineries unable to justify reconfiguration face a narrowing window before crack spreads, ETS costs, and CBAM exposure render operations unviable.
On the grid side, DERMS, ADMS, and virtual power plant platforms let DSOs actively manage the bidirectional flows created by rooftop solar, home batteries, EV chargers, and heat pumps. Grid-forming inverter mandates are becoming standard for new utility-scale assets as inverter-based resources displace synchronous generation. Smart meter rollout is largely complete in leading European markets, unlocking dynamic tariffs and demand response. V2G has moved into early commercial deployment through public transport and commercial fleets.
CBAM is live and reshaping the economics of carbon-intensive refinery output. The revised Industrial Emissions Directive is tightening BAT conclusions for furnaces and FCC units, while PFAS restrictions add liability exposure on legacy assets.
Operators that secured early SAF and HVO positions and built grid-side flexibility hold the advantage through 2030. Those deferring face compounding stranded asset risk and margin compression.
In the following, we highlight the three most critical supply trend developments. Download the complete list of all trends affecting the energy industry 2026+.
Data Centre Load Growth and Grid Stress
Current Situation: Data centre demand has become one of the largest new variables in grid planning. Ireland's data centres already exceed 20% of national electricity consumption, and US interconnection queues hold hyperscaler load requests above 100 GW in some regional transmission organisations. Congestion is concentrating in Northern Virginia, Dublin, Amsterdam, and Frankfurt, where local transmission capacity cannot absorb the requested load.
Expected Development: Demand is expected to grow 15 to 25% annually through 2028. Grid operators in Europe and the US will introduce dedicated large-load interconnection frameworks, and demand response obligations will become a condition of priority connection in some jurisdictions. Hyperscalers will continue procuring nuclear capacity, including SMRs, for firm round-the-clock supply. Waste heat recovery for district heating will scale in urban clusters.
Challenges: Transmission reinforcement takes 5 to 10 years while data centres are built in 2 to 3, creating a structural timing mismatch. Load concentration overwhelms specific grid zones rather than national systems. Hyperscaler round-the-clock clean energy commitments outpace the availability of firm low-carbon supply, since nuclear and long-duration storage cannot be procured at the speed load is being added.
Time to Maximum Impact: 0-2 years
Potential Impact: Very High
STEEP Segment: Technological
Grid-Forming Inverter Proliferation
Current Situation: Inverter-based resources are displacing synchronous generators, removing the inertia and voltage support that stabilised power systems for a century. Grid-forming inverters actively synthesise voltage and frequency instead of following the grid. Operators in Australia, Ireland, and Great Britain now mandate or incentivise the capability for new wind, solar, and battery projects following low-inertia stability incidents. ABB, Siemens, SMA, and Sungrow have commercialised products.
Expected Development: Mandates become standard in new European interconnection agreements between 2026 and 2028, with US regional transmission organisations following. Retrofit programmes for existing inverter fleets advance from 2028, supported by manufacturer firmware pathways. Distribution-level rollout begins scaling after 2030. The capability is a prerequisite for the 70 to 80% renewable penetration that leading European markets are targeting by 2035.
Challenges: Operational experience at high grid-forming penetration remains limited, and interactions between large numbers of grid-forming assets are not yet characterised. Grid codes and protection settings require coordinated revision across jurisdictions and system operators. Retrofit pathways vary by manufacturer and vintage, and some legacy assets need hardware replacement rather than firmware updates. TSO and DSO operations teams require substantial upskilling.
Time to Maximum Impact: 2-4 years
Potential Impact: Very High
STEEP Segment: Technological
Carbon Border Adjustment Mechanism and Trade-Embedded Emissions
Current Situation: CBAM entered its definitive regime in January 2026, requiring importers of steel, cement, aluminium, fertilisers, electricity, and hydrogen to surrender certificates matching the EU ETS carbon price. Trade flows and investment decisions are already shifting as non-EU producers decarbonise to protect European market access. The US, India, and China have challenged the mechanism's compatibility with WTO rules.
Expected Development: Scope expansion to refined petroleum products and chemicals is under consideration through 2030, and the phase-out of free ETS allocation will progressively raise exposure. Linkage with the UK and Canadian carbon prices is under discussion. For LNG and hydrogen exporters, demonstrating low methane intensity and low-carbon production becomes a precondition for competitive access to European markets.
Challenges: Calculating embedded carbon across multi-tier supply chains is difficult, particularly for hydrogen and LNG where upstream emissions vary sharply by production pathway. Methodologies remain under refinement and are applied inconsistently. WTO challenges create legal uncertainty. Divergent mechanisms in the UK, Canada, and the US risk producing a patchwork of incompatible carbon border measures for global energy traders.
Time to Maximum Impact: 0-2 years
Potential Impact: Very High
STEEP Segment: Political
Align your innovation roadmap with energy trends
