14AUG

Meta buys Wyoming solar from Enbridge

3 min read

10:48UTC

Enbridge will invest $1.2 billion in a 365 MW solar and 200 MW battery storage project in Wyoming serving Meta, entering service by end-2027, as operators chase firmed non-gas power away from the BTM fleet now under federal curtailment scrutiny.

← Back to GPUs now collateral as Nebius borrows $775m Jump to analysis ↓

IndustryDeveloping

Key takeaway

Meta is replacing BTM gas exposure with long-term firmed solar-plus-storage to reduce regulatory curtailment risk.

Meta signed an agreement with Enbridge, the Canadian pipeline company, for a 365 MW solar and 200 MW battery storage project in Wyoming, with Enbridge investing $1.2 billion and the project entering service by end-2027. ¹ It is Meta's largest renewable procurement to date and secures firmed power outside the behind-the-meter gas fleet.

The contract is the demand-side answer to the gas escape route's own queue. GE Vernova's turbine backlog, with deliveries stretching into 2029 , means an operator ordering BTM gas now waits years for it. With the DOE order also attaching curtailment risk to that fleet, an operator with the scale to contract at 365 MW has reason to switch generation type rather than join the turbine wait. A pipeline major taking the build is the tell: Enbridge is routing capital it would once have committed to gas infrastructure into solar-plus-storage for a single hyperscale customer.

The Wyoming deal does not run all day on its own, which is why the storage tranche matters and why Meta paired it the same fortnight with a gas-free baseload contract in New Mexico. Operators are no longer only moving where the power sits; they are changing what generates it.

Deep Analysis

In plain English

Enbridge is Canada's largest pipeline company, best known for moving crude oil and natural gas across North America. It is now building 365 megawatts of solar panels and a 200 MW battery storage system in Wyoming, enough to power roughly 150,000 homes, with Meta as the customer. Battery storage is the critical piece: solar alone only generates electricity when the sun shines. When you pair it with large batteries, you can store daytime energy and dispatch it at night, making the combination act more like a conventional power plant that runs around the clock. For Meta, this matters because its gas-powered backup generators can now be switched off by the grid in an emergency. Firmed solar-plus-storage cannot be curtailed the same way, so it reduces Meta's regulatory risk while also helping the company meet its carbon commitments.

Deep Analysis

Root Causes

Meta's procurement pivot from BTM gas to firmed renewables has two simultaneous drivers: the DOE 202(c) orders that reclassified BTM gas as interruptible grid reserve, and Meta's own 2030 net-zero commitment, which requires moving away from Scope 2 emissions from purchased electricity.

Enbridge's pivot from pipelines to renewable build reflects the structural demand signal: hyperscalers contracting 365 MW in a single deal with end-2027 delivery justify the capital allocation model of a pipeline company building renewable generation rather than simply transporting fossil fuels.

What could happen next?

Opportunity
Pipeline infrastructure companies with capital allocation models suited to multi-decade energy assets gain a new revenue stream serving hyperscaler renewable procurement at scale.
Risk
Solar-plus-storage reliance for 24/7 AI compute creates a winter reliability gap that may require supplemental gas or nuclear purchase during cold snaps, partially negating the regulatory risk reduction.

Source Landscape

This story draws on neutral-leaning sources

Primary parallel: Duke Energy's 2022 Resource Adequacy procurement in North Carolina placed a similar bet on solar-plus-4-hour-storage replacing retiring coal baseload, contracting 2.3 GW by 2025; actual winter reliability studies subsequently found a 600 MW reliability gap during cold snaps, leading Duke to retain two coal units past their scheduled retirement under a FERC cost-of-service order in January 2024.

Counter-parallel: Pattern Energy's 2024 SunZia Transmission project in New Mexico, the largest US transmission-connected renewable project at 3,000 MW wind with 550 MW storage, has delivered continuous 85-90 per cent capacity factor to Arizona Public Service under a firm supply contract, demonstrating that large-scale firmed renewables can meet firm-capacity standards when the wind and solar resource is strong enough.

At $1.2bn for 565 MW of combined capacity, Enbridge's per-MW cost of approximately $2.12m sits within the 2024-2025 US utility-scale solar-plus-storage range of $1.8-2.4m per MW as reported by the Lawrence Berkeley National Laboratory's Tracking the Sun programme.

For Meta, the deal converts an operating expenditure on grid capacity purchases into a long-term structured PPA (power purchase agreement), which can be capitalised differently on its balance sheet and provides a fixed-price hedge against the electricity price volatility that volatile BTM gas markets do not.

Meta raised its 2026 capex guidance to $125-145bn ; the $1.2bn Enbridge deal represents less than 1 per cent of that budget, giving it material flexibility to replicate this model across multiple markets.

Consensus view: BloombergNEF's renewable energy team has tracked the solar-plus-4-hour-storage levelised cost of energy falling below $70/MWh in Wyoming's wind and solar corridor in 2025, below Meta's estimated $65-75/MWh contracted rate for firm capacity in the PJM region; the Enbridge deal is therefore cost-competitive with grid capacity, a procurement arbitrage rather than a premium sustainability purchase.

Counter-view: RMI's electricity practice has questioned whether 200 MW of storage paired with 365 MW of solar in Wyoming will deliver the grid-firming reliability that hyperscalers need for 24/7 AI compute workloads; their 2025 hyperscale power modelling found that solar-plus-4-hour-storage reliably delivers only 12-15 per cent of nameplate capacity during winter demand events, making a heavy supplemental grid draw during December-February peaks likely regardless of the battery stack.

Key tension: Whether solar-plus-storage can genuinely replace gas-based firm capacity for 24/7 AI workloads, or whether it reduces gas exposure without eliminating the need for some gas backup, determines how much regulatory curtailment risk the Enbridge deal actually removes.

Sources:Utility Dive

Mentions:Enbridge →Wyoming →New Mexico →GE Vernova →FERC →Canada →Arizona →North Carolina →Meta →

First Reported In

Update #4 · Grid wins power to switch off data centres

Utility Dive· 26 May 2026

Read original →

Causes and effects

Caused by

DOE lets PJM switch off data centres

The DOE's Section 202(c) curtailment of BTM-equipped data centres accelerated Meta's pivot to non-gas firmed power, motivating the Wyoming solar-plus-storage deal with Enbridge.

Occurred 18 May 2026

Read story →

GE Vernova gas backlog hits 80 GW into 2029

GE Vernova's gas-turbine backlog extending to 2029 and regulatory curtailment risk on BTM gas made non-gas firmed power the logical alternative, driving the Enbridge Wyoming deal.

Occurred 1 Dec 2025

Read story →

This Event

Meta buys Wyoming solar from Enbridge

The deal marks a shift in operator procurement from gas-centric behind-the-meter generation toward firmed renewable baseload, in direct response to the curtailment risk the 202(c) orders attached to BTM gas.

Different Perspectives

Antel, Uruguay's state telecom

Antel will build a $70m AI data centre in Canelones, announced after an 11-12 August Council of Ministers meeting, with construction from Q1 2027 and roughly 250 direct jobs. Uruguay is putting a sovereign AI facility on the state balance sheet rather than courting a hyperscaler to build one.

Comtel

Comtel is building a Figline Valdarno data centre inside the H2-Era Green Valley complex, powered by an 84 MW solar plant and selling waste heat to on-site farming. Co-location with generation and a heat offtaker is the model regulators elsewhere are now writing into connection terms rather than negotiating case by case.

Greg Abbott, Texas Governor

Abbott directed PUCT and ERCOT on 3 August to audit every queued data centre's ownership, incentives and water use, saying projects that fail the state's survey should lose grid access. QTS's co-chief executives welcomed the review; Agriculture Commissioner Sid Miller called it too vague and wants a special legislative session instead.

Government of Gujarat

Gujarat notified a Data Centre Policy on 7 August offering capital, interest, tax and duty subsidies for projects sourcing at least 51% green power, targeting 7.5 GW against a 74 GW installed base. Where other jurisdictions priced or restricted grid access this month, Gujarat is paying developers to come instead.

Taiwan's Legislative Yuan Economics Committee

The committee gave preliminary approval on 5 August to a self-generation mandate for large power users, including data centres, with fines up to NT$750,000. It agreed the obligation in principle while leaving the megawatt threshold that defines its reach to later implementing regulation.

Australian Energy Market Commission

AEMC advised ministers on 5 August that data centres should surrender renewable certificates against actual consumption, prove new demand with new firm capacity, and register as market participants. The advice would turn passive customers into obligated participants inside the market's dispatch and settlement machinery, ahead of an access-standards determination due in late October.