A 2023 specification decision, not a 2023 fuel decision
Mexico released an updated Nationally Determined Contribution in November 2022, raising its unconditional emissions reduction target to 35% below a business-as-usual path by 2030, against a BAU projection of 991 MtCO2eq for that year, with 40% available if international support is provided. The previous pledge, made in 2020, was 22% (Enerdata, 21 November 2022).
Nothing in that commitment obliges a private plant in Monterrey or Altamira to burn a different fuel next year. What it does is set the direction that customers, lenders and eventually Mexican regulation will move in, and it does so on a timescale that collides with the equipment a heavy-industry operator is specifying right now. A process boiler or a reheat furnace bought in 2023 will still be on the site in 2045. The fuel decision is decades away. The decision that forecloses or preserves it is being made this budget cycle.
That is the argument of this piece. Low-carbon fuels are not a procurement question for Mexican industry in 2022. They are a capital specification question, and the operators who treat them that way will pay a fraction of what the operators who defer will pay to retrofit later.
What the IEA established, and at what scale
The International Energy Agency published The Role of Low-Carbon Fuels in the Clean Energy Transitions of the Power Sector in October 2021. Its useful finding for an industrial reader is a scale statement rather than a forecast. The IEA reports that co-firing of up to 20% ammonia and over 90% hydrogen has been carried out successfully at small power plants, with larger-scale test projects in development.
Read that carefully before drawing conclusions from it. Existing combustion equipment can accept a partial low-carbon fuel share without being replaced, which is what makes retrofit a credible pathway rather than a slogan. The demonstrated scale is small, and the IEA is explicit that the large-scale projects are tests. An operator can reasonably plan for fuel flexibility. An operator cannot reasonably plan for a hydrogen or ammonia supply chain in Mexico on a 2020s timetable, because none exists.
Mexican law already counts hydrogen as clean energy, and that is not the same as usable
Article 3, fracción XXII of the Ley de la Industria Eléctrica defines energías limpias broadly. Beyond wind, solar, hydro, geothermal and biomass, the definition expressly includes nuclear generation, efficient cogeneration meeting CRE efficiency criteria, thermal plants with geological carbon capture and storage, biogas and methane capture, and hydrogen combustion meeting minimum efficiency and lifecycle emission criteria. The statutory target that these count toward is a minimum 35% clean-energy share of electricity generation by 2024, set in Transitorio Tercero of the Ley de Transición Energética.
The gap between that definition and anything an operator can act on is the point. For hydrogen combustion to qualify, someone has to set and administer the minimum efficiency and lifecycle emission criteria, and that is a CRE function. SENER, which issues national energy policy and the PRODESEN, has not published a national hydrogen strategy. An industry association, the Asociación Mexicana de Hidrógeno, has been arguing for one. Until the criteria exist, a Mexican plant burning hydrogen has no defined standard to certify against and no mechanism to convert that into a Certificado de Energía Limpia or into anything a customer's procurement team will accept as evidence.
On our read, that argues for buying optionality rather than buying fuel. It also argues for taking efficient cogeneration seriously, because it is already inside the clean-energy definition, already has CRE criteria, and already pays back on fuel cost at sites with a steady thermal load.
The fuel risk that is already live is gas supply, not carbon
Mexican heavy industry runs on imported natural gas. SENER's balance data, as compiled by IMCO in August 2022, shows imports met 73.1% of domestic natural gas demand between January and September 2021. That basis matters, because press figures for Mexican gas import dependence range from about 70% to 90% depending on whether the denominator is consumption, supply or pipeline imports alone.
Dependence at that level has already interrupted production. CENAGAS, the independent manager and operator of SISTRANGAS, ordered restrictions on industrial gas consumption during the February 2021 Texas freeze, when supply from the United States fell away. For a plant with a continuous furnace, that is not an emissions problem. It is a lost-batch problem with a quantifiable cost per hour, and finance directors who have lived through one already know that number for their own site.
The commercial observation worth carrying forward is that the two problems have overlapping solutions. Dual-fuel capability, on-site fuel storage, firm rather than interruptible transport capacity, and cogeneration that raises the useful output per unit of gas all reduce exposure to a supply interruption today and reduce the cost of a fuel switch later. That is a rare case where the resilience case and the decarbonization case fund the same equipment, and it is the case to put in front of a capital committee, because the resilience half of it pays now. Our note on reliance on US natural gas sets out the exposure in more detail.
Ports and shipping, with the estimate labeled
Mexico has ports on both the Pacific and the Gulf, sits inside the United States-Mexico-Canada Agreement, and is the second-largest economy in Latin America. Those facts are why low-carbon marine fuels keep being raised as a Mexican opportunity. Green and blue hydrogen, green and blue ammonia, green methanol and biofuels are all candidate bunker fuels, and each requires different onshore handling, storage and safety infrastructure.
We estimate that adapting Mexican ports for zero-carbon bunkering would require between USD 1.7 billion and USD 2.7 billion of onshore infrastructure investment by 2030. That range is our own internal estimate. It is not drawn from a published dataset, it is not a costed engineering estimate for named terminals, and it should be read as an order-of-magnitude planning figure rather than a number to underwrite against. We state it because port-adjacent industrial operators are being asked to plan around a build-out whose scale nobody has published, and a labeled estimate is more useful than silence. It should be replaced with terminal-level costings as soon as any are available.
For an operator with a plant near Manzanillo, Lázaro Cárdenas, Veracruz or Altamira, the near-term implication is narrower than the headline. Bunkering infrastructure attracts industrial gas, ammonia and hydrogen handling capacity to the same corridors. Where that lands, it changes local fuel availability and it changes local electrical load, which changes what CFE Distribución can offer new connections in that corridor. Site-selection decisions made in 2023 should ask the question.
Specifications for the next burner purchase
The following belongs in the next combustion equipment purchase and in the next gas contract renewal at any Mexican industrial site:
- A written statement from the burner or boiler supplier of the maximum hydrogen or ammonia volumetric share the equipment accepts as delivered, and the scope and cost of the retrofit required to raise it.
- Materials compatibility in the fuel train, seals and instrumentation, stated by the supplier rather than assumed.
- Turndown range and combustion stability across the intended fuel blend, because a blend that works at full fire may not hold at part load.
- Your current Scope 1 fuel split by process, in energy units, with the delivered cost per GJ for each stream.
- Whether your gas transport capacity is firm or interruptible, and what the contract permits CENAGAS or your marketer to curtail.
- The cost per hour of an unplanned fuel interruption at each production line, calculated rather than estimated.
- Whether a cogeneration configuration qualifies under CRE efficiency criteria at your site's heat-to-power ratio.
None of that requires committing to a fuel. All of it is cheaper to obtain before a purchase order is signed than after.
Build fuel flexibility into the next capital cycle
Mexico Energy Partners can review a facility's fuel and power position together, covering gas supply firmness, cogeneration eligibility under CRE criteria, and what a fuel-flexible specification adds to the cost of equipment already in the capital plan. The initial review needs twelve months of gas and electricity billing, the current gas transport and supply contracts, a process fuel breakdown by end use, and the equipment list for anything due for replacement in the next five years. See our work with steel and metals and chemicals operations, and our approach to energy procurement in Mexico.