Fluor and JGC split $15bn LNG Canada phase-two EPC work

Fluor and JGC each signed $7.5 billion in EPC work for the second phase of LNG Canada this week, awards that add two liquefaction trains and a storage tank at Kitimat and double the site's capacity to about 28 million tonnes a year. The numbers are on the page, and the same week's renewable-energy announcements came without them.

On one side is a gas project—firm and dispatchable by design—with a price attached to each contractor; on the other are wind and solar deals from Texas to Shetland to New Zealand to Zambia that proceeded without disclosing a price, an offtake, or both. The pattern suggests capital terms are being published for new gas capacity while renewable developers are left to absorb merchant risk without a visible cost of capital.

Fluor and JGC were the same 50/50 partners on the first phase, and the second phase carries the same structure—two trains and a storage tank, with each contractor taking $7.5 billion—making the expanded Kitimat site a material piece of Pacific-basin LNG supply, though the announcement does not describe the contract type. The price alone is informative. $15 billion for roughly 14 million tonnes of new annual capacity works out to just over $1,000 per tonne, a figure an equity analyst can use.

Meta's solar contract with Apex Clean Energy in Texas, reported by Canary Media, names no capacity, term or price, and the outlet frames the agreement against Meta's continuing gas use—a reminder that a major tech buyer's renewable procurement is not replacing gas in its portfolio. The announcement tells us Meta is buying solar in Texas; it does not tell us how much, for how long, or at what cost.

Amazon's agreement with Statkraft is slightly more specific: the 36-megawatt Shetland onshore wind purchase is set for 2030 delivery, and Amazon says the contract joins a UK programme it counts at more than 50 agreements. The price and length of the PPA are not disclosed, so the 2030 date tells us when electrons flow but not what Amazon is paying or how long the obligation runs.

NZ Clean and Mercury took the same route in New Zealand, their agreement covering a 118-megawatt solar-storage park with Mercury named as the offtaker. The announcement omits the park's location, the price and the contract term, so the capacity is meaningful while the revenue terms are private.

Ørsted's construction start on the 200-megawatt Blackwater Solar project is the purest case of the week: PWD's tracking logged the announcement with no offtake agreement, no capital cost, no lender, no tax-equity participant and no financial-close date. A developer with Ørsted's balance sheet can build merchant, but the filing gives no indication whether this is merchant or contracted.

Globeleq reached financial close on a 40-megawatt solar project in Zambia without disclosing a construction cost, lender, tariff or offtaker—at the point where a project's capital structure is meant to be settled—and the announcement names only the capacity and the country. Alight's purchase of a 2-gigawatt Swedish solar pipeline, reported by Renewables Now, names the buyer and the capacity but omits the seller, project list, grid position and financing terms. Two gigawatts is a pipeline the size of several operating portfolios; the price is not part of the public record.

NexGen's Philippine solar off-take with a Marubeni affiliate is thinner still: Renewables Now names the two parties but not the signing entity, capacity, price or tenor. An off-take without capacity and price is effectively an intention; the market gets the headline and none of the economics.

The asymmetry is not a one-week accident. Across these seven transactions, the information that would let an outside observer price the transition is missing, while the LNG award publishes the cost of building new firm capacity. The renewables deals produce no comparable number—no cost per megawatt, no tariff, no debt-to-equity split. A single confidential PPA is not unusual. Seven announcements in a single week, across five geographies, without a single capital term is another.

The habit of undisclosed renewables terms may be familiar, but the contrast has consequences. If the cost of capital is invisible, the transition's pace and economics are harder to underwrite. Developers trying to contract with banks, tax-equity investors pricing basis risk, and corporate buyers who sign these off-takes cannot tell the market what they paid. That opacity does not stop projects—Ørsted is already building—but it does mean the public record is thinner for the assets meant to carry more of the load.

The $15 billion in EPC awards for two trains and a storage tank is the price of adding firm, dispatchable supply at Kitimat. The renewables side supplied capacity figures, dates and offtaker names, but no number that serves the same function, and whether that split persists will show up in the next project to reach financial close with its terms in the open.