Toby McKenna · CEO of Rockpoint Gas Storage (TSX-listed October 2025, Brookfield-backed), the largest independent natural-gas storage company in North America — 280 Bcf across six depleted-reservoir facilities in Alberta and Northern California. A 30-year gas trader turned midstream operator (NGX, Engage Energy, Louis Dreyfus/Castleton, co-founder of Tidewater Midstream).
His own company (CEO's book): the only listed pure-play gas storage in North America — 280 Bcf, ~30% share in Alberta and Northern California, ~80% EBITDA margin, ~5% dividend. Bull case is structural scarcity (four-part barrier to entry, "all that white space is spoken for") plus a Gulf-of-Mexico read-across that saw storage rates triple 10–12 years after first LNG. Trades at a discount to the infrastructure proxy because only ~50% of revenue is take-or-pay; targeting 60% by 2029.
Current owner of the Nimsdale storage facility McKenna built from the ground up at Tidewater — cited as the source of his land, regulatory and mineral-rights experience. Career reference, no stance.
Rockpoint's controlling shareholder (~60% of equity value in class B), which built the fleet from Warwick in 2012 through the Niska acquisition. The overhang: an Oct 15 lockup expiry, but a CPUC change-of-control application filed Q1 (needed to go below 50%) likely gates any sale to Q1–Q2 2027. "They love our business and aren't terribly excited about selling."
The private successor to Louis Dreyfus Energy Canada / LDH Energy, which he co-founded in 2003; credited for the bottom-up fundamentals and risk-management discipline he later applied at Rockpoint. Biographical reference.
The archetype of shale-era price elasticity that destroyed storage economics — drilling at $2–3, shutting in at $1. He argues that behaviour is structurally gone (liquids-rich targets, horizontals that can't be cycled), which is the whole bull case for storage spreads. Historical illustration, no stance.
Rockpoint's 49.9% non-op partner in the Tres Palacios salt-cavern facility, sold in 2023. No longer independently listed (acquired by Energy Transfer). Historical counterparty.
Named as one of the "large strategic integrates" that own most North American storage, and as the buyer of Rockpoint's 49.9% non-op Tres Palacios salt-cavern stake in 2023. Counterparty/peer reference, no stance.
One of the strategics that "love their storage" and own the competing fleet — the set-up for his "rising tide floats all ships" framing of storage scarcity. Peer reference, no stance.
The $13bn Alberta data-centre announcement, deliberately discounted: "there's more discussion about the demand than there has actually been FID projects." Macro tailwind reference, no stance.
Listed among the integrated strategics whose storage is captive to the parent — the reason Rockpoint is the only pure-play. Its NGTL system is also the curtailment risk Rockpoint's portfolio insulates customers from. Peer reference, no stance.
The company he co-founded with Joel MacLeod and ran to ~2020, built by rolling distressed gas processing, pipelines, rail and storage into a vertical chain (~30 transactions). Biographical reference; no view on the business today.
The M&A constraint: Williams trades at a multiple "much higher than Rockpoint", so buying storage from it at an accretive price is very hard. Storage is "really coveted" by its owners — which is why Rockpoint grows brownfield instead. Peer reference, no stance.
In one line: An operator source, not a manager — Rockpoint's CEO argues underground gas storage has become structurally scarce and structurally more valuable: shale's on/off price lever is broken, LNG and data-centre demand consume storage in ways heating load never did, and nobody can build a new depleted reservoir because the pipeline "white space" is already spoken for.
The asset is unreplicable, and the fourth barrier is the one nobody models. Geology is common (Alberta has "another dozen reservoirs" of comparable quality); location and pipeline cost are surmountable. What isn't: a new facility can't guarantee it can get gas onto or off a pipeline, because end users have contracted the delivery white space and producers the receipt white space. No proponent backstops that, so no board sanctions it. The only greenfield being built is small bespoke salt cavern in the southern US, serving a different need.
Shale used to cap every spread; that lever is gone. Producers now target liquids-rich and oil-associated gas — the dry-gas price barely enters their decision — and expensive horizontals can't be cycled on and off without damaging the well. So gas gets produced below variable cost for extended stretches (AECO ~$1 through Q3 last year; California below variable most of this summer), which widens spreads and raises the insurance value on the put rather than closing it.
Low gas prices are a tailwind, not a headwind. Storage is paid for access and timing, not price level. Gas that stays in the ground can be "transact[ed] on that same molecule over and over again with no risk" — and Rockpoint never forward-hedges a withdrawal, never carries an open long or short. Full storage this winter pushes low prices into next summer, which sets intrinsic value up to expand on the way out.
The Gulf of Mexico is his ten-year template for AECO. First Gulf LNG cargo 2014; nothing moved by 2015; today Gulf storage values are 300% of what they were. Two mechanisms: LNG-linked demand is inelastic in both seasons, and reserving injection capability takes ~3× the space a conventional utility user consumes — so conventional share shrinks while volatility grows. He calls AECO "on the precipice", explicitly not as guidance.
Insurance (non-intrinsic) value is the part that's compounding — not the summer/winter spread. Chicago printed $70 last winter, $1,000 in Oklahoma/Texas, $60 in California: a well-piped market with every incentive still couldn't attract molecules. He is deliberately declining 5–15 year contracts until that premium re-prices, and concedes this short-dated book is exactly why the stock trades below the infrastructure proxy (~50% take-or-pay, targeting 60% by 2029).
Revenue is three different risk businesses. Take-or-pay (paid regardless), short-term storage with banks (effectively a financing — the bank's own collateralised molecule sits in the ground), and a 15% "optimization" sliver that is an option, never an obligation — the distinction from a midstream marketing wedge, where imbalanced inlet/outlet substances force involuntary longs and shorts.
Capital goes brownfield, inside the fence. ~$150m over three years for 5–7% expansion at a 4–6× build multiple, plus an 11 MW battery at a Warwick site running at a third load factor. M&A is constrained because Williams and the other strategics trade at higher multiples and covet their storage.
Self-described 30-year bear now "a secular bull" on North American gas and the Canadian energy value chain — driven by LNG, oil-sands demand, ~10 GW in the Alberta power queue, energy sovereignty, and a decade-plus lag before pipelines can reconcile supply with demand. Caveats he names himself: a US/Canadian policy turn against LNG exports, a structural change in power generation, and faster-than-expected battery technology.
The overhang to track: Brookfield's ~60% class B stake. The Oct 15 IPO lockup lapses, but a CPUC change-of-control application filed in Q1 — required before Brookfield can drop below 50% — likely gates any real decision to Q1–Q2 2027, most plausibly via a secondary.
Transcripts
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