Oil spill: contained, but not clarified
A month after the first reports of oil washing ashore in Veracruz made headlines, the government is struggling to contain the fallout—both environmental and political. Meanwhile, the many political and environmental critics of Pemex and the government are pointing to the situation as grounds for demanding a full independent investigation.
The tar patches have now affected more than 600 kilometers of Gulf coastline, from Tabasco to the northern border of Veracruz, damaging marine ecosystems, beaches, and fishing and tourism communities. Federal authorities have offered varied explanations. Their most recent position holds that the spill originated from two natural seepages known as “chapoteras” and a private tanker (the company has not been publicly identified), denying that there is a leak at any Pemex facilities. Over 700 tons of crude oil have been collected to date in the government’s cleanup efforts.
Pemex critics have alleged contradictions between official statements and documented evidence. They have also questioned the handling of the spill’s environmental and social consequences.
Public records analyzed by El País show that the Pemex-contracted repair vessel Árbol Grande was anchored for nearly eight days (February 9 to 16) directly above an active underwater pipeline carrying Maya crude. This location coincides with an area where satellite imagery detected an oil slick exceeding 50 square kilometers. Satellite images and data from maritime-monitoring platforms further indicate that this point aligns with maintenance work on the Old AK-C pipeline, which links the AKAL-C platform with the Dos Bocas offshore terminal.
While this does not prove Pemex’s involvement, various NGOs and opposition voices accuse the government of distorting or downplaying information about the spill’s origin, pointing out that the denial of leaks at Pemex facilities potentially clashes with the prolonged presence of a repair vessel on an active underwater pipeline in the same spill zone. The agency continues to attribute the slick to a non-Pemex private ship and to natural subsurface seepage, but various environmental groups and analysts argue that natural seepage and a single unidentified vessel cannot plausibly account for the spill’s scale and duration. Thus, demands for independent investigations and full transparency have followed.
President Sheinbaum has announced she will meet with the Inter-institutional Group (Semar, Semarnat, Sener, Pemex, ASEA, Profepa) to review the work done on the spill and provide more information, emphasizing somewhat defensively that “it seems nothing has been done, but an enormous effort has been made.”
Meanwhile, Pemex recovered 549 cubic meters of crude in the area around the Dos Bocas refinery in Tabasco between March 20 and 22, following a spill linked to the refinery’s operations. This occurred days after a March 17 fire at the same refinery killed five workers. According to reports, oily wastewater from the plant flowed onto an access road and ignited a passing vehicle, though authorities have not yet established or disclosed an official cause.
As the Iran war drags on and global energy markets remain volatile, Mexico is feeling the pressure in gasoline and especially diesel prices, even as the government tries to cushion consumers with tax breaks and price‑cap agreements (that have been contested by some gas station owners). Mexico imports about 45 to 50 percent of its gasoline and diesel for domestic use.
To shield consumers, the Sheinbaum government has extended an existing agreement to cap regular gasoline at 24 pesos per litre and has activated temporary IEPS (fuel excise tax) reliefs, notably on diesel, to keep the national average of diesel around 28 pesos per litre instead of closer to 35 pesos market price. Officials stress that these measures are meant to protect the cost of transport and freight, since diesel is critical for cargo movement and the broader supply chain.
But grumbling from the private sector is getting louder. Gas station business sources told Bloomberg Línea on Tuesday that they had not formally accepted the government’s announced voluntary diesel price ceiling, arguing that the proposed cap leaves insufficient margin to cover last‑mile transport, labor, utilities, and other operating costs. The outlet reports that gas station representatives pushed for a higher maximum price, but the government instead proposed an even lower cap (around 28.28 pesos per litre for 30 days), highlighting a growing rift between the official narrative and the sector’s capacity to absorb constraints. Late on Tuesday, Pemex and Sener said the price stabilisation agreement with gas station owners had been “reaffirmed” at a price cap of 28.30 pesos per litre for diesel.
Analysts and institutions like the Institute of International Finance note that higher oil and fuel prices are already weighing on Mexico’s inflationary outlook and could slow growth by raising transport and production costs. Mexico is also entering its peak urea‑import season (April–June) just as the effective blockade of the Strait of Hormuz disrupts global fertilizer supply chains. Many major urea producers have cut or halted operations, pushing international prices up and making availability increasingly uncertain.
Because Mexico is heavily dependent on imported urea, this timing exposes farmers to higher input costs and supply‑chain volatility right when they most need fertilizer for planting. Higher fertilizer prices and constrained availability can lead to reduced applications, lower crop yields, and ultimately higher food‑price pressure if farmers pass on the added costs.
At the same time, the Finance Ministry has to weigh the fiscal cost of repeated subsidies of gasoline and diesel, especially if the conflict‑driven price surge proves persistent, which could strain the budget even as the government seeks to “protect” pump prices politically.
As the government struggles to control price spikes, an opportunity could open up in the illicit market for stolen fuel or “huachicol”, but so far, there have been scant reports of an increase in criminal activity. Pemex lost an estimated 23.5 billion pesos to fuel theft in 2025, 14.4% more than the year before.
A Petrobras and Pemex relationship? It’s complicated
Brazil’s President Luiz Inácio Lula da Silva has proposed a joint venture between Pemex and Petrobras to exploredeepwater and ultra‑deepwater fields in the Gulf of Mexico, where Mexico currently has no commercial deepwater production despite holding promising acreage. Petrobras is one of the world’s most experienced deepwater operators, having developed Brazil’s massive pre‑salt basins at depths over 2,000 meters, so the logic is that Pemex could gain access to advanced drilling, subsea, and reservoir‑management technology without shouldering the entire learning‑curve cost.
For Mexico, the alliance could help reverse years of declining oil output by opening new frontiers beyond mature onshore and shallow‑water fields, supporting President Sheinbaum’s target of around 1.8 million barrels per day. Joint projects could also reduce the capital intensity for Pemex, since Petrobras would bring proven deepwater expertise and potentially share in investment and risk, while allowing Mexico to leverage its own resource base instead of relying heavily on imports of refined products. Analysts frame this as a chance to strengthen regional energy integration and give Pemex a technological “upgrade” without fully privatizing or opening blocks to foreign majors.
However, the upsides for Petrobras are harder to define. Imagine that Petrobras offered an agreement allowing foreign companies like Pemex to invest in joint ventures on mature fields—where production is already advanced and requires highly specialized technology—under a model that leaves Petrobras with at least 40 percent (and possibly up to 80 percent) participation in exchange for its existing licenses and infrastructure, while requiring its partners to fund 100 percent of the development capex. In that context, Pemex would almost certainly turn it down: not only because its upside would be structurally capped by Petrobras’ minimum stake, but also because it lacks the capital to shoulder the front‑loaded investment. That is, in effect, the kind of mixed‑contract scheme Mexico offered last year, and Petrobras has little reason to be interested in such arrangements.
Instead, Petrobras’ preferred model is closer to “farm‑out” type projects, like the partnership Pemex has with Woodside in the deepwater Trion field, where an experienced operator comes in to share risk and expertise while the national company retains a significant but not necessarily controlling share. Petrobras would also be drawn to standalone blocks in deep or ultra‑deepwater Mexico, similar to those offered in the 2014–2018 bidding rounds under Enrique Peña Nieto. However, Mexico currently offers nothing of that kind, and even if it did, Petrobras is not a global “super‑major” racing to grab acreage everywhere, on the scale of Shell, Chevron, or Total.
In refining, the case for a Pemex–Petrobras joint venture is even weaker. Beyond rare cases such as Mexico’s former Deer Park joint venture with Shell—where Mexican heavy crude was sent across the border to be turned into gasoline and returned to Mexico—there is little precedent for cross‑border refinery partnerships. Deer Park made logistical and economic sense for a specific supply chain; shipping crude or refined products between Mexico and Brazil would be a logistical overkill with few clear benefits.
In short, there is little room today for a mutually profitable Pemex–Petrobras partnership in the Gulf of Mexico. That does not mean, however, that Mexico has nothing to gain from observing Petrobras’ own trajectory. About two decades ago, Petrobras was one of the most indebted oil companies in the world. Through a deliberate shift—improving corporate governance, divesting some refining assets, and focusing the business plan on profitability—it became a financially self‑sufficient, investor‑attractive company, with a minority part of its business listed on the stock market. Even under President Lula da Silva’s return to office, that basic separation between the state and corporate strategy has not been fully undone, and the company has retained a degree of political independence.
Pemex could learn from this path: not by replicating Petrobras’ exact model, but by tempering Mexico’s current narrative that the government must tightly control energy companies and protect monopolies at all costs. Sheinbaum can reframe how a progressive administration engages with state‑owned firms, balancing public‑policy goals with long‑term financial and technical sustainability.
Negotiations are still in an exploratory phase, with Petrobras’ CEO, Magda Chambriard, scheduled to visit Mexico City in April to discuss the scheme with Pemex leadership and federal officials, so no binding deal exists yet. The partnership would have to navigate Mexico’s stringent energy‑sovereignty stance, Pemex’s financial fragility, and environmental‑regulatory constraints, especially after the recent Gulf spill and other controversies around the Dos Bocas refinery. Any agreement is likely to be politically sensitive at home, as it touches the symbolic value of Pemex, even if framed as a technical alliance rather than a full liberalization of the sector.
Any Pemex-Petrobras would have to navigate Brazil’s October 4th and 25th 2026 Presidential elections. Betting markets now put pro-Trump Flavio Bolsonaro (son of ex-President Jair Bolsonaro) as very slight favorite to beat Lula. It would be tough to imagine a Bolsonaro-controlled Petrobras working with 4T-controlled Pemex.
But the domestic legal victory does not end the controversy. Mexico is also facing international litigation over its lithium policy through a World Bank arbitration. Bacanora Lithium, Sonora Lithium and Ganfeng International Trading have filed an ICSID claim against Mexico tied to the Sonora project and the cancellation of nine concessions, arguing that a broader set of state measures effectively nationalised lithium and harmed their investment. The case, ARB/24/21, was registered in June 2024 under the China-Mexico and UK-Mexico bilateral investment treaties. The claimants are seeking damages, interest and costs. While no compensation figure has been disclosed publicly and the proceedings remain pending, the amounts sought are thought to go from hundreds to billions of dollars. (An ISDS America Latina Excel sheet listing claims against Mexico shows an entry for “Bacanora Lithium Limited, Sonora Lithium Ltd., Ganfeng International Trading… v. México”)
In any case, the Supreme Court ruling does not solve the harder problem, which is execution. Mexico has now largely secured the legal right to monopolise lithium, but that is very different from demonstrating the technical, financial and institutional capacity to develop a viable lithium industry under a state led model. The centre of gravity now shifts from courts to implementation: whether LitioMx can move beyond symbolism, whether the government can build a credible industrial chain around the mineral, and whether a model with limited private participation can compete with faster moving jurisdictions. In that sense, lithium is no longer mainly a constitutional question. It is now a test of state capacity.
That gap matters because it highlights the difference between strategic intent and operational reality. Reducing import dependence is not just a production challenge. It requires infrastructure, storage, transport, permitting, execution discipline and a regulatory environment capable of supporting investment and efficiency. As long as imports remain structurally high, Mexico’s electricity system and large industrial base remain exposed to supply disruptions, price volatility and logistical bottlenecks tied to the US gas market. The ambition of greater self-sufficiency remains politically attractive, but the current evidence suggests the country is still much closer to managing dependency than overcoming it.
Even so, the move is politically significant. Cárdenas carries deep symbolic weight in Mexico’s energy debate, and his presence gives the commission the potential to function as a source of legitimacy in discussions that may become increasingly sensitive, especially around gas policy, the role of private capital, and the strategic direction of Pemex under Sheinbaum. The risk, of course, is that the commission becomes more symbolic than operational. But even a consultative body with limited formal power can matter if it is used to frame, endorse or soften politically difficult shifts in policy. In energy politics, symbolism often precedes substance.
What is emerging is not a return to the previous liberalised model, but a hybrid system in which private capital can participate only within a state-defined planning logic. That may help mobilise investment without ceding control, but it also raises questions about execution, incentives and transparency. Many of the projects still lack clearly visible public detail on individual budgets, permitting status and financing structure. The risk is that ambition outpaces implementation, particularly where transmission bottlenecks, environmental approvals, rights of way and dependence on gas fired generation remain unresolved. CFE’s expansion push is real, but its success will depend on whether centralised planning can deliver at the speed that the system now requires.
The timing matters as much as the appointment itself. ASEA sits at the centre of environmental oversight and industrial safety enforcement for hydrocarbons, so rapid turnover at the top can translate into shifting criteria, uneven enforcement and uncertainty for operators. At a time when regulatory credibility is already under pressure, leadership instability risks reinforcing the perception of an institution reacting to crises rather than shaping compliance predictably. For the market, this raises the possibility of a tougher or less consistent supervisory environment, especially if the new leadership seeks to respond forcefully to recent incidents and public criticism.
The loss of investment grade is more than a reputational blow. It is likely to raise financing costs, narrow the pool of eligible investors and make future refinancing more expensive at a time when capital discipline matters more, not less. For a company as significant as Orbia, the episode is also a reminder that industrial and petrochemical players tied to global cyclical demand remain vulnerable to sustained margin compression and balance sheet deterioration. In practical terms, the downgrade increases pressure on management to restore credibility through stronger cash generation, asset discipline or operational restructuring.