HIGH CONFIDENCE FOR SELECTED SECTORS; LOW CONFIDENCE ECONOMY-WIDE | STRATEGIC JUDGEMENT
What if the geography of growth is determined by access to energy?
Verdict
Timely access to firm, affordable, low-carbon and connectable electricity will become one of the strongest location constraints for energy-intensive industry, AI computing, hydrogen, electrified logistics and some housing growth. It will not displace talent, agglomeration, ports, fibre, water or quality of place. TCE’s opportunity is to help create energy-to-value ecosystems, not simply to move demand towards generation.
Evidence anchorsIEA, 2025 · NDRC, China, 2023 · METI/MIC Japan, 2025 · Central Electricity Authority, India, 2023
AWhat is changing
Electricity demand rises as transport, heat, industry, cooling and digital infrastructure electrify. The decisive variable is not annual national generation but local and temporal access: whether a project can connect within its investment window, at a competitive delivered cost, with adequate firmness and flexibility. A location near offshore wind can remain power-constrained if transmission, distribution and system services are absent.
Demand is beginning to follow supply selectively. China is coordinating western computing hubs with renewable-energy bases through East Data West Computing. Japan’s Ministry of Economy, Trade and Industry and communications ministry are developing “Watt-Bit” coordination to align data infrastructure with power availability. India is building renewable-energy corridors and industrial nodes. These are active spatial policies, not evidence that market demand will automatically relocate.
Ports are becoming energy-industrial platforms. Offshore wind, floating assembly, cable logistics, hydrogen derivatives, carbon dioxide transport, component manufacture and electrified freight can cluster around selected coastal locations. The risk is that coastal regions host generation and infrastructure while high-value engineering, finance, data and ownership remain elsewhere.
FORECAST
UK electricity demand is expected to rise materially by 2050 across official pathways, but the range is wide. Demand growth is a scenario-dependent planning assumption, not a single forecast.
OBSERVED
The IEA estimates global data-centre electricity use at about 415 TWh in 2024, rising to roughly 945 TWh in 2030. Local impacts are much more concentrated than the global share suggests (IEA, 2025).
BThe bolder interpretation
The edge view is a new hierarchy of places defined by the lowest risk-adjusted cost of dependable power on time. Traditional prime locations may face a “connection discount”, while secondary locations with firm capacity, water, fibre and planning gain a premium. This would not eliminate cities; it would bifurcate activities. AI training, electro-intensive production and hydrogen may decentralise, while leadership, finance, research and client-facing services remain clustered.
A second edge is that energy abundance can entrench extractive regional models. China’s western provinces illustrate the possibility that energy and computing capacity are relocated without equivalent local decision-making or high-value employment. For the UK, the relevant question is whether ports and coastal communities become integrated production ecosystems or remain infrastructure hosts.
CGeographic evidence
| Lens | Emerging model | Implication |
|---|---|---|
| UK / Europe | Exceptional offshore resource but acute grid and permitting constraints. Regional plans and the Strategic Spatial Energy Plan aim to align demand, generation and networks. | Energy can unblock or block growth, but existing metros will often pay to retain activity. |
| China | Western and northern energy bases, ultra-high-voltage lines and computing relocation are coordinated at state scale. | Demand geography can be influenced, but coastal agglomeration and western resource dependence persist. |
| India | Renewable corridors and industrial states create fast-growing load centres; discom weakness, land and water constrain delivery. | National transmission is not the same as reliable local access. |
| Japan | Hokkaido and Kyushu are potential clean-power and data hubs, but interregional transfer and energy import dependence remain constraints. | Coordination can be deliberate even in a dense, mature economy, but system architecture limits relocation. |
EvidenceNDRC China, 2023 · CEA India, 2023 · METI/MIC Japan, 2025
DStakeholder effects
| Segment | Value | Likely conflict |
|---|---|---|
| Energy-intensive occupiers | Connection certainty and firm low-carbon power | Will reject sites with nominally cheap energy but uncertain delivery |
| Knowledge-sector occupiers | Talent, fibre, amenity and reliable distribution | Power constrains expansion but rarely determines location alone |
| Rural / coastal communities | Jobs, infrastructure and lower bills | May reject export-enclave development and cumulative landscape cost |
| Utilities / networks | Coordinated demand and investable reinforcement | Face contested cost allocation and long lead times |
| Local government | New fiscal base and industrial identity | Risk of stranded sites or low local value capture |
| Households | Reliable affordable electricity | Potential competition with industrial and data loads through network charges |
EImplications for The Crown Estate
TCE’s distinctive opportunity lies at the interfaces it already touches: seabed, cables, coastal landing points, ports, rural land, urban demand and spatial evidence. The strategic unit should be the energy-to-value ecosystem a coordinated package of generation, networks, flexibility, port capability, industrial demand, skills, housing, nature and community benefit.
- Marine leadership: use spatial planning and leasing to align offshore generation with cables, ecological constraints, ports and future demand rather than treating projects independently.
- Coastal enabling: structure partnerships so ports and communities capture operations, manufacturing, skills and infrastructure value not only temporary construction activity.
- Urban exposure: assess distribution-grid capacity and cooling demand as development constraints. Preserve flexibility for occupiers whose load profiles change rapidly.
- Rural exposure: anticipate substations, overhead lines, storage and renewable development as cumulative place changes requiring landscape and benefit-sharing strategies.
- Capital allocation: prioritise shared infrastructure and capacity that unlocks multiple users, while avoiding speculative “energy parks” that depend on unresolved grid or demand assumptions.
Core trade-off
Concentrating demand near energy can improve system efficiency and reduce network costs, but may concentrate environmental burdens and economic power. Distributing local value can reduce pure financial return or speed, yet may be necessary for consent and national legitimacy.
FStress test
The original question overstates energy as a determinant and under-specifies the quality of access. It captures a major location constraint but should focus on where energy can genuinely move activity, which complementary assets are required and how local value is retained.
Rewritten question
For which activities will timely access to firm low-carbon power reshape UK growth geography and how can TCE ensure energy-hosting places capture durable value rather than only infrastructure burden?
Provocations
- What if a credible connection date becomes more valuable than proximity to London?
- Which activities can follow power without losing the agglomeration benefits that make them productive?
- Should local communities receive energy access, ownership or fiscal benefit before national capacity is expanded?
Board prompts
- Where can TCE combine marine, coastal and urban levers into a coherent ecosystem?
- What evidence would distinguish a genuine industrial cluster from a subsidised energy enclave?
- How should cumulative community and ecological impacts be reflected in leasing and investment?
- Which energy-access advantages should be preserved as options rather than committed to one user?
Signpostsconnection offers and delivery dates; regional electricity pricing; data-centre and hydrogen siting; port investment; local supply-chain content; community benefit models; curtailment and flexibility markets.