Behind-the-Meter Power for Data Centers Market (2026-2036)

The growth of this market is mainly driven by the gap between data centre construction schedules and grid interconnection timelines, which obliges operators to procure generation they control in order to energise capacity at all; the scale of load associated with artificial intelligence computing, which exceeds the headroom available at many points of interconnection; the availability of gas turbines, reciprocating engines and fuel cells that can be delivered and commissioned within the construction window; and the willingness of hyperscale operators to contract power capacity in gigawatt-scale frameworks rather than megawatt increments. In addition, the emergence of energy-as-a-service structures that remove generation from the data centre balance sheet, the development of small modular reactors for later in the forecast period, and regulatory determinations that are reshaping how co-located generation and load are treated are further shaping the growth of this market.

The Behind-the-Meter Power for Data Centers Market, also referred to as the on-site data centre generation market, data centre microgrid market or co-located data centre power market, comprises the electricity generating and storage assets installed on the customer side of the utility meter to supply a data centre campus. The market includes natural gas generation through aeroderivative and industrial gas turbines and reciprocating engine gensets, solid oxide and proton exchange membrane fuel cells, on-site solar photovoltaic generation, battery energy storage deployed as part of a behind-the-meter power system, small modular nuclear reactors intended for later deployment, and dual-fuel, hydrogen-ready and waste heat recovery equipment. It also covers the switchgear, controls, microgrid management and interconnection protection required to operate such a system, together with engineering and construction, operations and maintenance and energy-as-a-service provision. The market ecosystem extends from equipment manufacturers through engineering and construction contractors, independent power producers and energy service companies to hyperscale operators, colocation providers, enterprises and the regulators and transmission operators whose rules determine how on-site generation may be connected and settled.

The driver of this market is a timing mismatch rather than a cost advantage. A data centre campus can be designed, permitted and built in a period measured in quarters, while the transmission studies, network upgrades and interconnection agreements required to serve a load of several hundred megawatts are measured in years. Where those two schedules diverge, the operator either leaves a completed facility unenergised or procures generation it controls, and the economics of an idle artificial intelligence campus make the second option straightforward to justify.

That logic has translated into demand at a scale few anticipated. In the third quarter of 2026, Bloom Energy Corporation reported revenue of USD 1,235.8 million, up 138.1% from USD 519.0 million a year earlier, with product revenue of USD 1,073.6 million, up 179.4%, GAAP operating income of USD 225.4 million at an 18.2% margin against 1.5% a year earlier, and adjusted EBITDA of USD 299.5 million against USD 59.0 million, and raised full-year 2026 revenue guidance to USD 4.4 billion to USD 4.6 billion from USD 3.9 billion to USD 4.2 billion. Revenue growth of 138.1% and the move from a 1.5% to an 18.2% operating margin indicate a supplier whose capacity is being absorbed as quickly as it can be built, and the transition from loss to substantial profit at this rate of growth is characteristic of a market in which buyers are competing for delivery slots rather than negotiating on price.

Capacity is now being contracted in frameworks rather than projects. Bloom Energy holds a framework agreement with Oracle for fuel cell capacity of up to 2.8 GW, of which 1.2 GW is firmly contracted, and has expanded its financing framework with Brookfield to USD 25 billion. A single agreement providing for up to 2.8 GW, with 1.2 GW firmly contracted, and a financing framework of USD 25 billion behind it, indicates that hyperscale operators are securing on-site generation in the same way they secure land and construction capacity, which converts an equipment market into a capacity reservation market.

The same pattern is evident in gas generation. In the second quarter of 2026, GE Vernova Inc. reported revenue of USD 11.1 billion, up 22%, orders of USD 24.2 billion, up 88% organically, and total backlog of USD 176 billion, with Power segment orders of USD 16.7 billion, up 134% organically, gas equipment backlog rising from 44 GW to 53 GW, and gas equipment backlog and slot reservations rising from 100 GW to 116 GW, with at least 125 GW expected under contract by the end of 2026. Gas equipment backlog and slot reservations rising from 100 GW to 116 GW in a single quarter, with at least 125 GW expected under contract by year end, indicates that turbine manufacturing capacity is reserved years forward, so an operator deciding today on gas generation is negotiating for delivery late in the decade rather than for the next construction season.

Data centre demand is explicitly identified as the cause. GE Vernova stated in July 2026 that its data centre orders had reached over USD 5 billion year to date, more than double its full-year 2025 total. Orders from this sector more than doubling against the prior full year, at a company whose turbines serve utilities and industry worldwide, quantifies how rapidly data centre procurement has become a principal source of demand for generation equipment generally, not only for equipment configured for behind-the-meter use.

Regulation is now the most consequential variable in the market, and it is moving in a direction many participants did not expect. On 18 December 2025, the Federal Energy Regulatory Commission issued an order in PJM Interconnection, L.L.C., 193 FERC 61,217, Docket EL25-49-000, finding the PJM tariff unjust and unreasonable for lacking clear terms for co-located load, directing PJM to establish interim non-firm transmission service, firm contract demand service and non-firm contract demand service with penalties for withdrawals above contracted levels, with compliance filings due on 20 January and 16 February 2026. The Commission has required co-located load to take defined transmission services with contract demand limits and penalties, rather than leaving the arrangement to be structured privately between a generator and a load.

The determination on netting is more consequential still. In the same order the Commission found that behind-the-meter generation netting is no longer just and reasonable for large loads because it can shift costs to other customers, directed PJM to set a megawatt materiality threshold limiting the load that may be netted against behind-the-meter generation, grandfathered contracts entered into specifically to create such arrangements, and provided a three-year transition period. Behind-the-meter netting was the mechanism by which a large load co-located with generation could reduce the transmission charges it paid, and removing it above a materiality threshold changes the economics of the arrangement rather than the engineering. The practical consequence is that behind-the-meter power for a large data centre is increasingly justified by speed of energisation and by control over supply rather than by avoided network charges, and the three-year transition period is the window in which existing arrangements must be restructured.

Technology selection follows deliverability more than any other criterion. Reciprocating engines and aeroderivative turbines can be delivered and commissioned fastest and dominate bridge applications; solid oxide fuel cells offer high efficiency, low local emissions and modular delivery that suits constrained urban sites and permitting regimes hostile to combustion; industrial gas turbines in combined cycle offer the lowest cost per megawatt hour at campus scale but the longest lead time; and small modular reactors are contracted for the second half of the forecast period rather than available now.

The market includes equipment manufacturers, microgrid and energy service providers and advanced nuclear developers, among them Bloom Energy, GE Vernova, Caterpillar, Cummins, Siemens Energy, Mitsubishi Heavy Industries, Wartsila, Rolls-Royce, Generac, Schneider Electric, Eaton, Oklo, NuScale Power, FuelCell Energy, Mainspring Energy and Enchanted Rock. Participants compete on deliverable capacity and lead time, cost per megawatt hour delivered, emissions and permitting profile, footprint and water requirement, fuel supply and firmness, ability to operate in island and grid-parallel modes, reliability and availability guarantees, and the financing structures offered alongside the equipment.

At the same time, the market faces challenges, including gas supply and pipeline capacity at the chosen site, air permitting and local opposition to combustion generation in populated areas, equipment lead times that are themselves now measured in years, the removal of netting benefits in the largest wholesale market, the commercial unavailability of small modular reactors within the first half of the forecast period, and the risk that interconnection reform narrows the timing gap on which the market depends. As a result, suppliers that combine deliverable capacity in the near term, acceptable emissions and permitting profiles, credible availability guarantees and financing that removes the asset from the customer balance sheet are expected to capture the largest share of growth over the forecast period.