Access to capacity on the electricity grid is quietly becoming a binding constraint in real estate development — alongside zoning, permitting, and financing. Auxilium Infrastructure Partners’ perspective on what that means for site selection and development risk.
The conventional feasibility checklist for a real estate development is well established. Is the zoning in place? Can financing be secured? Does market absorption support the scheme? These questions have structured development decisions for decades, and they remain valid. But for a growing number of projects, a new constraint is entering the picture — one most developers have not yet built into their feasibility analysis: access to capacity on the electricity grid.
This is not a niche issue for specialist energy projects. It is becoming a practical constraint on delivering conventional commercial and residential development, particularly in locations under concentrated electrification pressure. Developers who do not understand their grid exposure are carrying a risk they have not yet named.
A scarcity that used to be invisible
For most of the postwar development cycle, electricity was a commodity input. A site needed a connection; the connection was made; the project proceeded. The technical details — transformer capacity, voltage levels, available amperage at the connection point — were handled by engineers after the development decision had been taken. They did not determine whether a project was viable.
That assumption is breaking down. The energy transition is driving an unprecedented, simultaneous increase in electricity demand across nearly every asset class. EV charging, heat pumps replacing gas systems, data centres, industrial electrification, and battery storage all draw on the same grid nodes. In many locations across Denmark and Northern Europe, capacity is already constrained or close to it. Energinet paused new transmission-level connection agreements earlier this year as requests reached levels the network had not previously seen.
The consequence for development is direct. A mixed-use scheme with substantial EV charging, heat pump heating, and a modern electrical fit-out may need far more grid capacity than the same scheme would have a decade ago. Where that capacity does not exist at the local substation or primary grid node, it cannot simply be ordered. It must be waited for — or paid for through network reinforcement contributions that may never have been modelled.
Grid proximity is becoming a site selection variable
For site selection, the implication is that proximity to high-voltage infrastructure — substations, primary grid nodes, 60 kV or 150 kV lines — is beginning to carry development value that was not previously recognised. A site adjacent to a well-connected substation has access to a resource that a site one kilometre away may not. In a constrained network, that difference can decide whether a scheme is delivered on programme.
This is not yet systematically reflected in land pricing or feasibility practice. Most development appraisals treat the electricity connection as a cost item with low uncertainty, rather than as a constraint with binary consequences. That treatment was reasonable when network capacity was abundant. It is less reasonable now.
Exposure varies by asset class
The constraint does not bear evenly on all development types. Residential schemes in urban areas face the highest pressure, particularly where district heating is unavailable and heat pump adoption is high. Large commercial developments with significant EV charging requirements face similar dynamics. Logistics and industrial development — increasingly electrified and often located at the edge of urban grid networks — forms a third category of exposure.
By contrast, development served by recent grid investment, or where existing connections retain spare capacity, faces limited near-term risk. The constraint is geographically uneven — which makes grid capacity a site-specific question rather than a general sector concern.
The logistics parallel: how infrastructure gets repriced
Motorway proximity was not always priced into logistics and industrial real estate the way it is today. The value of a site one kilometre from a junction versus seven was once a secondary consideration. As supply-chain economics became more granular and last-mile pressure intensified, access to transport infrastructure became a primary valuation driver.
The same mechanism is now at work in energy infrastructure. A characteristic that was previously ignored, or treated as an operational detail, is moving toward explicit recognition in how sites are valued. The repricing will not happen overnight, and it will not apply uniformly — but the direction of travel is clear, and it favours developers and investors who account for grid proximity before it becomes consensus.
Three questions developers should ask early
The implication is not that every project needs a specialist grid study; for many sites the constraint will not bind. But for development in urban growth areas, in locations with concentrated EV or heat pump penetration, or on dormant sites whose connection capacity may have been reallocated, three questions are worth answering early:
How much capacity is available at the nearest substation?
Where does the project sit in the queue for capacity upgrades in that network area?
Has the scheme’s electrical load been sized against actual available capacity, rather than assumption?
These questions can be answered early in the development process at relatively low cost. Discovering the constraint late — after planning consent has been secured and programme commitments made — costs far more.
Auxilium Infrastructure Partners works at the intersection of energy infrastructure and real estate, developing battery storage and flexible energy assets on sites where grid capacity and physical characteristics align. We welcome conversations with developers and investors beginning to think about these dynamics.