Why the timing question is different from the hedge decision
Two questions confront every Mexican industrial gas buyer: should I hedge my natural gas exposure, and when to hedge? Most treasuries assume these are the same question. They are not.
The decision to hedge is strategic. It answers whether the company will convert price volatility into predictable cost. The decision of when to hedge is tactical. It answers what the entry point should be, what instrument, what percentage of exposure, and what tenor.
Confusing the two produces predictable errors. A CFO who decides “we should hedge” and then executes immediately at whatever price the market offers gets suboptimal timing. A CFO who spends months debating the strategic question misses windows. Both errors are avoidable with a disciplined decision framework.
This post covers the tactical question of timing. The strategic case for hedging natural gas in Mexico is covered in the natural gas hedging guide for Mexico. Here we focus on the operational framework that determines when to move.
Three forces that drive the timing decision
The right moment to hedge is not a single price target. It is the calibration of three separate forces that any Mexican industrial buyer needs to read simultaneously.
The first force is the current price level relative to historical context. Where do current HSC or Henry Hub prices sit against their 5-year range? Cheap prices favor immediate action. Expensive prices favor waiting or partial coverage.
The second force is the shape of the forward curve. Are futures more expensive than spot (contango), or cheaper (backwardation)? Each regime implies different hedging behavior.
The third force is internal constraint. Budget cycles, approval processes, hedge accounting documentation, and organizational authority all shape when a treasury can actually execute. A perfect market window means nothing if the internal machinery cannot move.
None of these three forces alone determines the timing decision. Their combination does. Different buyer profiles weigh them differently, but every serious hedging program considers all three.
Reading price levels against historical context
Price level is the easiest force to read, but the most commonly misread. The standard question is: is the market cheap or expensive right now? The answer requires a benchmark.
The correct benchmark is the 5-year range of the specific index the buyer is exposed to. If the supply contract references HSC, look at the HSC 5-year range, not Henry Hub. The two do not always move together, and using the wrong reference generates hedges that do not match the exposure. The U.S. Energy Information Administration publishes historical price data that supports this kind of 5-year analysis.
The 25th to 75th percentile band matters. When HSC trades in the bottom 25% of its 5-year range, hedging is cheap insurance. When it trades in the top 10% or 25%, the buyer is paying a fear premium built into elevated volatility. The middle range demands more nuanced reading, and the appropriate action depends on the shape of the forward curve and internal constraints.
The common trap is using a 12-month lookback instead of 5 years. Twelve months captures only recent memory and misses full price cycles. A 12-month view might frame current prices as “high,” while a 5-year view frames the same level as mid-range. Different framings produce opposite hedging decisions.
For Mexican buyers tracking multiple indexes, the monthly HSC report from InHedge Intelligence provides 5-year distributions updated monthly, so treasuries do not need to build the analysis from scratch each cycle.
Reading the forward curve
The forward curve tells the buyer what the market expects, and what the market expects has direct implications for hedging. Real-time forward curves for Henry Hub futures are published by CME Group.
When the forward curve is in contango, futures prices are higher than spot. The market expects prices to rise. Locking in a swap in contango means paying more than the current spot price. The cost of certainty is baked into the curve. Not all contango is equal. Steep contango often reflects supply concerns or seasonal demand ahead. Shallow contango is closer to normal.
When the curve is in backwardation, futures prices are lower than spot. The market expects prices to fall. Locking in a swap in backwardation effectively captures a discount to spot. Backwardation is often the better window to hedge because the swap itself provides an economic benefit beyond just certainty.
The classic timing mistake is hedging in deep contango because the buyer expects prices to rise further. The market has already priced that expectation into the curve. Paying up in contango often locks in a spike that has already peaked. Sophisticated hedgers do the opposite: they act in backwardation when the market expects declines, capturing the discount.
Interpreting backwardation persistence matters too. A single month of backwardation may reflect seasonal factors. Six months of persistent backwardation signals a fundamental bearish market view. The instruments used at each moment differ. The financial hedging guide for natural gas covers the specific instruments and how each responds to curve dynamics.
Internal constraints that shape timing
The market often gives the right window. The treasury cannot always take it. Understanding why internal constraints delay optimal timing is essential for building a program that survives real corporate reality.
The budget cycle trap is the most common. Many Mexican companies approve annual budgets in November or December. Once the budget is signed, the treasury has a fixed price to defend. If the market offers a good hedging window in July, the treasury cannot always act because the budget assumes a different price. If the market offers a bad window in November because prices spiked, the treasury hedges anyway because the calendar demands it. The result is systematically bad timing driven by the annual cycle, not by market signal.
Approval authority creates a similar problem. If moving the hedge ratio requires a risk committee that meets quarterly, the treasury cannot respond to a two-week window. By the time the committee approves, the window has closed.
IFRS 9 documentation is a hidden constraint. Without proper hedge accounting documentation, the mark-to-market of derivatives hits P&L directly. Boards and auditors get nervous. The treasury scales back hedging to avoid accounting volatility, not because the underlying exposure is smaller. This is a solvable problem but requires investment in documentation that many treasuries defer.
The realistic answer is not that these constraints disappear. They do not. The answer is that a hedging program must be designed with them in mind. Timing rules should build in the delays and cycles the internal machinery imposes, so the program works in practice, not just in theory.
Different consumer profiles determine when to hedge
Not every Mexican buyer weighs the three timing forces the same way. Three profiles illustrate the variation.
A combined cycle power generator with a 20-year offtake contract has a fundamentally different timing calculus. Long-dated hedges make sense because the underlying obligation is long-dated. Internal constraints are less pressing because the exposure is contractually fixed and defensible. Price level and curve shape dominate. This buyer might hedge multi-year positions when backwardation appears, even if internal cycles do not align perfectly.
A manufacturer optimizing quarterly margin faces a different problem. Exposure changes with production volume. Internal budget cycles are more relevant because quarterly margins get reviewed. Price level and curve shape still matter, but timing is heavily conditioned by production forecasts. This buyer typically rolls shorter-tenor hedges more frequently, matching hedge to expected consumption cycle.
An importer focused on cross border logistics weighs basis risk more heavily than absolute price. The critical timing question is not just when to hedge Henry Hub, but when to hedge the basis differential to HSC or Waha. Their timing may be dominated by pipeline maintenance calendars and LNG export cycles more than by macro price levels.
Each profile is legitimate. The mistake is applying a single timing rule across all profiles as if hedging were a uniform practice.
When NOT to hedge and why timing matters
The disciplined counterpart to knowing when to hedge is knowing when not to. Hedging at the wrong moment or with the wrong conditions creates a different kind of risk than not hedging at all.
Do not hedge when exposure cannot be defined with precision. A treasury that does not know how much gas the company will consume in the next 12 months cannot know how much to hedge. Hedging estimated volumes leads to over-hedging or under-hedging, either of which defeats the purpose.
Do not hedge when the budget cannot absorb the cost of premiums. Options and structured hedges require upfront premium. If that premium is not budgeted, the treasury either skips protection or funds it from other lines, creating internal friction that undermines the program.
Do not hedge when the authority to act is not in place. If the treasury needs board approval for every hedge but the board only meets twice a year, the practical result is a program that hedges twice a year at whatever the market happens to be. That is not a program. That is calendar-driven timing.
Do not hedge without hedge accounting documentation. Applying derivatives without IFRS 9 support means P&L volatility hits earnings without the offset from the underlying exposure. Boards react, hedging gets scaled back, and the program dies from accounting resistance rather than economic failure.
The discipline of not hedging badly is as important as the discipline of hedging well. For companies evaluating whether their program has the right foundations in place, the contact page is the starting point.