Briefings go to clients first. When the action window closes and the data is no longer market-sensitive, the brief becomes a public artifact — sanitized where it has to be, intact where it can be. This is the library. It grows as the cadence does.
ERCOT's 2026 summer reserve margin sits below the reliability target. Combined with continued data center load growth and lagging dispatchable generation buildout, summer carries real exposure for unhedged commercial customers. Here's the scenario range and what to do before peak season.
Corporate PPA demand hit a record in 2025: more than 28 GW of contracted capacity. Supply hasn't kept pace. For net-zero roadmaps signed in 2023 expecting 2025-26 pricing, the math has changed.
PJM's recent Base Residual Auction cleared at levels commercial customers haven't budgeted for in a decade. The next nine months are about getting ahead of bills that land starting mid-2026 — and the brokers who don't surface this proactively will lose renewals to those who do.
Winter volatility is elevated. Forward curves show backwardation favoring locking. LNG export demand is firming. Utility rate filings are pending. The case for spring 2026 fixed-rate procurement in Illinois isn't subtle — it's a confluence of indicators most customers won't piece together themselves.
The 'AI demand' story has been in every utility filing and analyst report for eighteen months. What's new is that the forward curves are pricing it in. For 2027-2030 power and gas, the curve shape has shifted in ways that show consensus modeling is catching up to what hyperscaler announcements have been telegraphing.
The GHG Protocol's Scope 2 Guidance update — now in stakeholder review — proposes tighter rules on what counts as a market-based emissions reduction. For RE100 commitments, REC sourcing, and PPA strategy, the implications are material. Here's what's likely to change and what to do now.
Three new US LNG export terminals come online between Q2 2026 and Q4 2027, adding roughly 7.5 Bcf/d of takeaway capacity. The forward curve is pricing some of this — not all. For domestic gas buyers, the question isn't whether prices firm; it's when the curve shape catches up to the demand reality.
The Northeast gas market enters the heating season with structural setup that diverges from recent years. Pipeline constraints, LNG export competition, and weather asymmetry create real decision points for commercial customers exposed to NE/NY winter prices.
Most commercial customers have no idea what a forward curve is. Their advisors do — but explaining the curve to a CFO who wants 'just the answer' is its own skill. A practitioner's primer on how to read curves and translate them into the language customers actually use.
SB-253 and SB-261 require GHG emissions reporting and climate-related financial risk disclosures from companies operating in California above revenue thresholds. With implementation phasing in 2026, every multi-state operator with CA revenue should understand what's coming.
Battery storage at commercial sites has been pitched for years. The economics have been marginal — until now, in specific markets and use cases. Here's where the math now works, where it doesn't, and the customer profile that justifies investment.
NYISO's capacity market is on a separate trajectory from PJM. Demand curve resets, CLCPA pressure on dispatchable generation, and locational pricing dynamics in NYC and Long Island are reshaping the outlook. For NY commercial customers, planning needs to update.
Final 45V Treasury guidance defined what qualifies for the hydrogen production tax credit. Less stringent than environmental groups wanted, less generous than developers assumed. For customers exploring hydrogen as decarb strategy, the credit math now has clearer rules.
Demand response has been a 'nice-to-have' for most commercial customers. That's changing. Capacity reform in PJM, ancillary services updates in ERCOT, and new programs in MISO are reshaping the DR revenue stack. For 2026, customers with curtailable load are looking at meaningfully different economics.
The PJM capacity market jumped from $28.92 to $269.92/MW-day — surprising most of the industry. We weren't fully surprised. But we were also wrong about timing and magnitude. A retrospective on what the analysis got right, what we missed, and what we're watching now.
Permian basin associated gas has traded at significant discount to Henry Hub. That discount is now compressing as takeaway capacity additions catch up to production growth. By 2027, basis may behave very differently than the procurement structures of the last five years assumed.
Commercial customers default to calendar-driven procurement — renew when the contract ends. But the calendar doesn't know what the curve is doing. Here's how to think about timing as a separate decision from contract status.
Briefings go to subscribing clients first — typically 3-4 weeks before the public catalog gets them. If your team makes energy decisions monthly, the live cadence is how the practice is meant to work.