Baja California runs on a power system that is not connected to the rest of Mexico. The Sistema Eléctrico de Baja California is a member of the Western Electricity Coordinating Council and ties to California through two international connection clusters, at Tijuana and Miguel and at La Rosita and Imperial Valley. It does not tie to the Sistema Interconectado Nacional. Neither does its gas system.
For a plant in Tijuana, Mexicali or Ensenada that is the operating fact that matters. When capacity is short in Baja California, no amount of surplus generation in Sonora or Jalisco can reach it. The state's reserve margin, its gas supply from the United States and its own generation fleet are the whole of the story, and they are tighter than the headline capacity number suggests.
Our read is that the arithmetic usually quoted for Baja California overstates what is available to serve local load, and that any facility in the state should be treating self-generation and load management as risk controls rather than as cost initiatives.
The capacity number is not what it looks like
The Institute of the Americas, in Baja California Energy Outlook 2020-2025, published on 11 February 2020, counted 14 operational utility-scale power plants in Baja California with a combined installed capacity of 4,049 MW, of which 1,102 MW is destined for export to California. Subtracting one from the other gives the frequently quoted 2,947 MW of effective installed capacity.
That subtraction needs care, because the two quantities are not the same kind of thing. The 4,049 MW is nameplate capacity of physical plant. The 1,102 MW is a contractual commitment to serve load north of the border. It is not a measure of energy delivered, which varies hour by hour, and it does not mean 1,102 MW of steel is unavailable to Baja California under any circumstance. What it does mean is that a little over a quarter of the fleet is built and contracted to serve a different market, so the capacity a facility in Mexicali can count on in a tight hour is closer to the lower figure than the higher one.
Set that against demand. The same report puts maximum hourly demand at 2,800 MW in 2018 and projects 3,530 MW by 2025. Against 2,947 MW of nominally available capacity, before any allowance for planned outages, forced outages or derating in summer heat, the margin in 2018 was thin and on that demand path it closes. CENACE, which operates the system and dispatches it, has the same arithmetic in front of it.
Cerro Prieto did not start at 720 MW
Cerro Prieto is Mexico's largest geothermal field and the second largest in the world by capacity in operation, and it is operated by CFE. It is also routinely described as having opened at 720 MW in 1973, which is wrong and materially so.
CFE commissioned the first two 37.5 MW units of Cerro Prieto I in 1973, with two more of the same size following in 1979. Cerro Prieto II and Cerro Prieto III added 220 MWe each between 1986 and 1987, and Cerro Prieto IV added 100 MWe across four 25 MWe units in 2000. The 720 MWe figure is the peak reached after nearly three decades of build-out, not a starting point. Those figures are from Geothermal energy in Mexico: update and perspectives, which also records the four original 37.5 MWe units being retired in 2011 and 2012 and physically removed in 2016, leaving 570 MWe in operation as of December 2019.
Actual output has fallen further, to roughly 340 MW, on declining steam supply. The Institute of the Americas report estimates that efficiency measures at the field, including recovering excess steam pressure and improving the fluid transport network, could add around 83 MWe. It also puts Baja California's untapped resource at 6,550 MW of solar, 3,495 MW of wind and 2,000 MW of geothermal. That is potential, not a pipeline. Against it, the same report identifies roughly 636 MW of utility-scale solar actively under development and around 100 MW of wind likely to come online within four years.
The reason the gap between resource and build stays open is the isolated grid itself. Power generated in Baja California cannot be sold into the national market without transmission that does not exist, so a developer's addressable demand is the state, plus whatever it can contract into California. That narrows the offtake pool, and it is a bigger constraint on new renewable capacity in Baja California than irradiation or wind speed ever will be.
Gas: a capacity number and a consumption number, frequently confused
Baja California produces no natural gas and imports all of it. It consumed roughly 340 million cubic feet per day in 2019, of which about 93% went to power generation, split 45% public sector and 55% private, again per the Institute of the Americas report.
The same report gives the combined volume of Baja California's international gas border crossings as 2 billion cubic feet per day. That figure is border-crossing capacity, not throughput, and it is roughly six times the state's own consumption. Treating it as delivered gas is a common error and it makes the state's supply position look far more comfortable than it is. Capacity to move gas is not the same as gas contracted, and neither is the same as gas that will flow on a February morning when demand in the US Southwest spikes. CENAGAS has ordered restrictions on industrial gas consumption during exactly that kind of event.
For a plant manager, the practical question is not the pipeline number. It is whether the facility's electricity supply, whether from CFE Suministro Básico or a Suministrador de Servicios Calificados, sits behind gas-fired generation with firm transport, and what the contract says happens when it does not.
Who does what, and why it matters here
Three institutions are usually collapsed into one in coverage of Baja California, and the distinction affects who a facility talks to. CRE is the regulator: it issues generation and supply permits, approves regulated tariffs and sets the rules for distributed generation. CENACE operates the system, dispatches generation and runs interconnection studies. CFE is a state productive enterprise and a market participant, not a regulator, and it is the operator of Cerro Prieto and the counterparty for distribution-level interconnection through CFE Distribución. A tariff question goes to CRE's published schedules. An interconnection question goes to CFE Distribución or, for larger projects, through CENACE.
What a facility in Baja California can act on
Onsite generation is the option least exposed to the state's transmission and offtake constraints, because it never uses either. Generación distribuida in Mexico is capped at generating capacity below 0.5 MW, under SENER's Manual de Interconexión de Centrales de Generación con Capacidad menor a 0.5 MW, published in the DOF on 15 December 2016, and CRE Resolución RES/142/2017, published in the DOF on 7 March 2017. The limit applies to the generating capacity of the plant, not to the facility's load, and it is written in MW of capacity rather than kWp of DC panel rating, which is a different measurement. Staying below the threshold removes the CRE generation permit but not the interconnection contract with CFE Distribución under the small and medium-scale regime, and that contract governs the schedule.
The contract modality decides what surplus output is worth. Under medición neta, exports are credited against the site's own consumption for up to 12 months rather than sold, with only unused credits paid at the Precio Marginal Local. Facturación neta values generation and consumption separately at hourly market prices, and venta total is the only outright sale. Our note on distributed generation in Mexico sets out the regime in full, and the benefits of onsite solar in Mexico covers how a system is sized against a plant's load shape.
Onsite solar in Mexico is commonly presented as delivering savings of up to 25%. Savings in this range are measured against current CFE supply and vary with tariff class, region, load factor and consumption profile. The figures are illustrative. No range can be confirmed for a specific site without interval data and 12 months of billing. In Baja California there is a second reason to run the numbers rather than take the range: the DIST tariff applies a semi-punta period in winter that does not exist elsewhere in the country, which changes when generation is worth most.
A grid-tied array without storage does not keep a plant running through an outage, because anti-islanding protection disconnects it. In a system with the reserve margin described above, that distinction is worth putting in front of the operations team before it is tested.
Assess your exposure on the Baja California system
Mexico Energy Partners can review a Baja California facility's supply arrangement, tariff position and interruption exposure, and size what onsite generation would and would not cover. The review needs 12 months of CFE billing, interval data where the meter records it, the site address and a single-line diagram. Energy monitoring at the site is usually the first thing we recommend, because the load shape decides most of the answer.