Record Barrels, February Prices: The Brent Spike Slips Into Q2 While Debt and Capex Absorb the Windfall

Results vs. Consensus

1Q26 Scorecard

Income Statement, 1Q26 vs. 1Q25

Quality of the Print

Revenue. The headline growth of 11.7% flatters the quarter. Sequentially, revenue of $23,535M was 0.3% below the $23.6B of 4Q25, in a quarter when Brent averaged 27% higher than the prior three months and total own production rose 3.7%. Three things absorbed the difference. Total sales volumes fell 4.6% sequentially to 3,217 Mbpd on ordinary first-quarter seasonality in Brazilian fuel demand. Crude exports fell 11.1% sequentially to 888 Mbpd, partly because cargoes lifted at the very end of March were not accrued in the quarter. And the price realized on what did ship reflected February trade dates rather than March screens. None of that is a demand problem; all of it is a calendar problem.

Margins. Gross margin of 48.2% was 111 bps below 1Q25, and operating margin fell 118 bps. Depreciation, depletion and amortization rose 26.6% YoY to $4,111M as P-78, P-79, Alexandre de Gusmao, Anna Nery and Anita Garibaldi moved from construction into service. That is the arithmetic price of the growth: a 16% production increase carries a 27% depreciation increase before a single barrel is sold. Selling expenses rose 39.0%, which reflects the higher export freight and handling associated with a record export programme. Two line items flatter the operating result and should be stripped: the $417M net impairment reversal (versus a $50M loss a year ago), essentially all of it in Refining, and the $175M reduction in exploration costs. Together they account for $642M, or more than the entire $572M YoY increase in operating income.

EPS. The distance between the $0.96 reported and the roughly $0.70 recurring figure is the cleanest illustration of what this quarter actually was. Net finance income contributed $1,467M, of which $2,118M was foreign exchange and inflation indexation gains arising from the real's appreciation against the dollar on a largely dollar-denominated liability stack. That is a translation effect on the balance sheet, not cash, and it is precisely what the company's own recurring measure removes. Reported earnings rose 3.8%; recurring earnings rose 12.5%; the Street wanted 50%.

Segment Performance

Exploration & Production

E&P produced 3,197 Mboed in Brazil, up 16.4% YoY and 3.8% sequentially, with pre-salt volumes of 2,189 Mbpd carrying the increase. Ten new producing wells came online in the quarter, seven in the Campos Basin and three in Santos. Búzios reached eight platforms in operation, and Búzios and Tupi both now sit above the one million barrel per day mark. This is the segment doing exactly what the business plan promised, and doing it early: P-79 began production on May 1, three months ahead of schedule.

The earnings did not follow. Segment revenue rose 6.2% on a 16.4% volume increase, which means the realized value per unit fell roughly 9% YoY. Almost all E&P revenue is intersegment (US$15,937M of US$15,996M), so the segment line reflects internal transfer pricing as much as market realization, but the direction is unambiguous and it is compounded on the cost side: E&P cost of sales rose 19.8%, driven by depreciation on the newly commissioned units. Gross profit fell 5.0% and pre-tax operating income fell 2.9%.

"In the first quarter of 2026, we produced 2.58 million barrels of oil per day. In April, we significantly produced 2.73 million barrels of oil per day, a new monthly record for Petrobras."
— Fernando Melgarejo, Chief Financial and Investor Relations Officer

Assessment: A 16% volume increase that delivers a 3% earnings decline is the single most important number in this release, and it did not come up once in Q&A. The volume growth is real and durable; the earnings conversion depends entirely on price, and price is the variable Petrobras controls least.

Refining, Transportation & Marketing

Refining produced 1,816 Mbpd of oil products, 6.7% above 4Q25 and 6.4% above 1Q25, at a 95% utilization factor that was six points better than the prior quarter and reached 97.4% in March, the highest monthly reading since December 2014. Diesel output rose 7.4% sequentially, jet fuel 21.8% (against a 4Q25 base depressed by the REVAP turnaround), and S-10 diesel set a monthly record of 512 Mbpd in March. Pre-salt crude made up 69% of processed feedstock, and higher-value products (diesel, gasoline, jet fuel) were 68% of output. LPG imports fell to 26 Mbpd, the lowest quarterly volume the company has reported.

The financial result was extraordinary. Segment revenue rose 11.5% while cost of sales fell 5.4%, taking gross profit from $1,211M to $4,525M and pre-tax operating income from $475M to $3,519M. Three forces are at work, and they are not equally durable: crack spreads widened sharply once Middle East supply was disrupted; the feedstock was cheap relative to the product slate for most of the quarter; and a federal diesel subsidy allowed domestic prices to be held below import parity without Petrobras absorbing the difference. A $414M impairment reversal sits inside the segment result as well.

"In terms of our refining park, the utilization factor reached at 97.4%, which recently, due to the war between the U.S. and Iran, has now surpassed 100%."
— Magda Chambriard, Chief Executive Officer

Assessment: Roughly a third of the segment's YoY improvement is non-recurring or policy-dependent (the impairment reversal plus the subsidy mechanism). The operating half of it, meaning six points of utilization and a richer product mix, is genuine and repeatable. Investors should underwrite the utilization, not the spread.

Gas & Low Carbon Energies

The smallest segment swung from a $44M pre-tax loss to $168M of income on an 18.5% revenue increase. Natural gas sales rose 2.2% sequentially and 15.0% YoY as fertilizer units in Bahia and Sergipe started up; domestic gas deliveries rose 8.3% sequentially, displacing Bolivian imports (down 22.2%) and LNG regasification (effectively nil). Electricity sales rose 45.1% sequentially. Petrobras also contracted nine thermoelectric plants in the 2026 capacity reserve auction, roughly 2.6 GW of firm power for 2026 through 2031, with estimated fixed revenue of R$44B over the contract period.

Assessment: Small in absolute terms but strategically the most improved part of the portfolio. The auction contracts convert idle thermal capacity into contracted, Brent-independent revenue, which is exactly the kind of earnings the rest of this company does not have.

Operating Metrics

Two rows in that table explain the revenue miss on their own. Total sales volume fell 4.6% sequentially and crude exports fell 11.1%, in the quarter when the price of what Petrobras sells rose the most. The export mix also shifted hard toward Asia: China took 62% of crude exports (up from 52% in 4Q25 and 33% in 1Q25) and India 15%, following new contracts with IOC and MRPL alongside renewals with BPCL and HPCL. Concentration in a single buyer at 62% is now a genuine portfolio characteristic rather than a rounding item.

Cash Flow, Returns and Balance Sheet

Key Topics & Management Commentary

Overall Management Tone: Management was assertive to the point of swagger on operations and conspicuously conservative on money, and the two registers never quite met. Production records, refinery utilization and project acceleration were presented as evidence of an organisation exceeding its own design limits, while every question that reached the cash line was answered with the same three-step hierarchy of investment, then debt, then possibly shareholders. Pushback was narrow and civil, concentrated on capital allocation under a higher oil price, and management's answers there were framework-level rather than quantitative.

1. The Price Lag: Why a 51% Brent Spike Produced a Flat Revenue Quarter

Brent entered 2026 near $61 a barrel, reached $71.5 by mid-February, and then broke sharply higher after military action in the Middle East on February 28 and the effective closure of the Strait of Hormuz. The month of March alone carried a move of roughly 51%, with the quarter closing near $118. Petrobras's own release puts the 1Q26 average 27% above 4Q25, which implies an average in the $80s against a $118 exit. The company recognised almost none of the spike, and the CFO explained why in the prepared remarks rather than leaving it to Q&A.

"First, the rise in Brent prices is not reflected in the first quarter results because the price surge began in March. Exports recognized this month are mostly priced in February when they are traded and shipped from Brazil to their destinations. All the prices we got in March, or most of them, was still priced before these higher oil prices. We will start seeing this increase in the second quarter of 2026."
— Fernando Melgarejo, Chief Financial and Investor Relations Officer

Assessment: This is a credible and verifiable explanation rather than an excuse: the export-volume and mix data in the operations report corroborate it independently. It also means the 1Q26 print carries almost no information about earnings power at current strip prices, and that anyone underwriting the stock on 1Q26 numbers is underwriting the wrong quarter in both directions.

2. The Export Backlog: Roughly 80,000 Barrels a Day Deferred Into 2Q26

Beyond the pricing lag, physical volume also slipped across the quarter boundary. Crude exports of 888 Mbpd were 11.1% below 4Q25 despite record production, and the operations report notes cargoes exported at the end of the quarter that were "consequently, not accrued in 1Q26."

"Furthermore, the record production levels had virtually no impact on earnings because we had a backlog of exports amounting to around 80,000 barrels per day, which is another important point that will sustain our results for the second quarter. This inventory will be monetized at a higher price than it would have been in the first quarter."
— Fernando Melgarejo, Chief Financial and Investor Relations Officer

Inventories consumed $778M of operating cash in the quarter, roughly double the $359M drawn a year earlier, which is consistent with a build of unshipped barrels. The company did not quantify the revenue value of the backlog.

Assessment: Eighty thousand barrels a day for a quarter is roughly 7.2 million barrels. At the difference between a low-$80s realization and a $110-plus one, the deferred value is material to 2Q26 but not transformational on its own. The larger 2Q26 driver is simply that the whole export book reprices, not that the backlog clears.

3. Record Production Meets Falling Upstream Earnings

The upstream delivered a 16.4% production increase and a 2.9% decline in pre-tax operating income. Depreciation, depletion and amortization for the group rose 26.6% to $4,111M as five FPSOs moved into service, and E&P cost of sales rose 19.8%. Every barrel of the growth arrives with its own depreciation attached, which is normal for a capital-intensive ramp but is not costless.

"Three factors have sustained this production growth. More projects to increase capacity, such as new oil rigs, increased operational efficiency, which has strengthened the stability of our operations, and an efficient reservoir management."
— Fernando Melgarejo, Chief Financial and Investor Relations Officer

Assessment: The volume story is intact and, on P-79's three-months-early startup and the Almirante Tamandare capacity uplift, running ahead of plan. The earnings story requires a price environment that 1Q26 did not provide and 2Q26 probably will. This is the pillar most exposed if Hormuz reopens.

4. Refining Carries the Quarter

The refining system was the swing factor in group earnings, contributing $3,044M of the $572M YoY increase in group operating income while E&P went backwards and corporate costs rose. A six-point sequential jump in utilization is a large move for a system of this size, and management stated it has since gone further.

"Concerning refineries, we've ended the quarter at 95, 97. We're operating at 100 and 102, 103%. Since yesterday we've been at 103%."
— William França, Chief Industrial Processes and Products Officer

Management framed the ambition well beyond the current plan, moving from a 2026 to 2030 target of supplying 85% of Brazilian diesel demand toward outright self-sufficiency in diesel and gasoline. RNEST is the vehicle: the first train was described as running at 140,000 barrels a day against a 115,000 design, with 150,000 under test.

Assessment: Refining self-sufficiency is the most underappreciated part of this story. A domestic-diesel-short Petrobras is a price-taker on imports and politically exposed every time crude spikes; a diesel-long Petrobras converts the same spike into export margin. The 2030 timeline is long, but the direction of travel changed this quarter.

5. The Subsidy Architecture: R$1.50 a Litre and a Receivable From Brasilia

Petrobras did not pass the March crude move through to Brazilian pump prices. It did not absorb the loss either. The federal government stepped in with a diesel subsidy, granted in two tranches within a month of the conflict starting, and the mechanism now underwrites the gap.

"In March, the war broke out on February 28. In March, exactly on the 12th, we had a subsidy from the federal government about diesel prices. Within 12 days of the war, we got a BRL 0.70 subsidy. After 15 days, we also got another one with an additional BRL 0.80. The domestic market currently has a subsidy of BRL 1.50."
— Magda Chambriard, Chief Executive Officer

The CEO was explicit that the arrangement is profit-neutral to positive for the company, and separately that the subsidy is large enough to cover imported barrels as well as domestic production: "the BRL 1.52 real subsidy that's being proposed by the government is enough to let us import diesel and supply it to the Brazilian market."

Assessment: Mechanically this works and, for now, it works in Petrobras's favour. Structurally it converts a commodity exposure into a sovereign receivable, and it makes the company's downstream margin a function of fiscal willingness rather than of the crack spread. That is a different risk, not a smaller one, and it is not priced as one.

6. Working Capital and the Collection Question

The subsidy shows up first as an accounts receivable, and the amount recognised in the quarter was modest relative to the size of the gap it is covering.

"Starting with the subsidies in March, it's they're in accounts receivable. They've been accounted for in our BRL 740 million results. Now it's only a matter of procedures, and we expect to get paid within this quarter. As for the other ones, there is still an ongoing operational workflow that needs to be completed before we get paid."
— Fernando Melgarejo, Chief Financial and Investor Relations Officer

Operating cash flow fell 1.2% YoY despite a 3.8% increase in net income, with working capital a net drag: inventories consumed $778M, other assets $673M and trade receivables $245M, partially offset by a $717M increase in production and other taxes payable.

Assessment: A collection cycle that runs through a federal ministry rather than a customer is the item to monitor in 2Q26. If the receivable converts on schedule, the cash conversion improves markedly and the deleveraging path resumes. If it does not, working capital absorbs the very windfall the market is waiting for.

7. Gross Debt Moves the Wrong Way at $71.2 Billion

Gross debt rose $1,421M sequentially to $71,214M, of which finance debt was $27,537M and lease obligations $43,677M. The company's stated target is convergence to $67B during 2026 and $65B by the end of the plan horizon, against a ceiling of $75B.

"Looking now at gross debt, we remain within the limit set out in our business plan below $75 billion. We closed the quarter with $71.2 billion in gross debt, a slight increase, but the trend is downward. I reiterate our expectation of convergence to $67 billion in 2026, and $65 billion by the end of the plan. It may be even smaller, lower than that."
— Fernando Melgarejo, Chief Financial and Investor Relations Officer

Management's defence is that leases dominate the balance: "over 60% of the total debt comes from leases that, under accounting standards, must be recognized as debt. These amounts are associated with assets that generate production and consequently revenue for the company." That is true, and the lease stack is 61.3% of gross debt on the reported figures.

Assessment: Reaching $67B by December from $71.2B in March requires more than $4B of net reduction in three quarters, in a company that is simultaneously adding projects to the budget and paying out 45% of free cash flow. Higher Brent makes it achievable. The point is that it is now contingent on Brent rather than on the plan, and the first quarter went the other way.

8. Capital Allocation Hierarchy: Investment, Debt, and Shareholders Last

Asked directly whether a stronger oil price would translate into extraordinary distributions, the CFO laid out an explicit ordering and put the shareholders at the end of it.

"Our priority becomes investments, and that's why we decided to have the base and target CapEx, so that we can securely add new funding projects there. We have already added a few, and if there are no additional projects for the period, the next item in the agenda would be to pay the debt so that we can converge towards $65 billion or less."
— Fernando Melgarejo, Chief Financial and Investor Relations Officer

Assessment: Consistent, disciplined and unambiguous, and also the opposite of what a large part of the ADR's shareholder base owns the stock for. A company whose payout policy is a formula on free cash flow, run by a management that will spend free cash flow first, delivers a smaller and more volatile distribution than the formula implies.

9. Capex Under a $118 Tape: SEAP Pulled Into the Budget

Total investments were $5.1B in the quarter, 25.6% above 1Q25. On the plan-tracking basis management uses on its target slide, $4.5B of a $16.9B annual figure had been spent, or 26.6% of the year in the seasonally lightest quarter. Operating expenses of $5.6B against a $20.2B annual forecast tracked at 27.7%, which the CFO attributed to exchange rates, transportation costs and higher production. Meanwhile projects previously excluded from base capex are being pulled in.

"We've just included SEAP with 22,000 million cubic meters. That's the capacity that we're talking about. They were not on our budget, and now we have included them on our budget. They were outside of our base CapEx, so we are evolving in that regard."
— Fernando Melgarejo, Chief Financial and Investor Relations Officer

The CEO framed the same decision from the top: the Sergipe Deepwater project now has two platforms approved, together capable of 240,000 barrels a day and 22 million cubic metres a day of gas processing.

Assessment: The flexibility mechanism is working as designed, and pulling high-return pre-salt projects forward at $118 Brent is the right call on returns. It is also the mechanism by which the windfall never reaches the debt target or the distribution. Both statements are true simultaneously, and the market has to choose which one it is buying.

10. The Breakeven Framework: $59 Today, $48 to $50 by 2030

The most useful disclosure on the call was not about this quarter at all. Pressed on planning assumptions, the CFO gave a breakeven trajectory rather than a price forecast.

"The company has been getting prepared to work with a Brent balance of $59. This is what we foresee in the company regardless of our future Brent prices. We stated this in our strategic plan. We ran the company last year at around $81 for a balanced Brent, and we expect it to reduce until the end of 2030, to around $48 or $50, regardless of what happens."
— Fernando Melgarejo, Chief Financial and Investor Relations Officer

Assessment: A cash breakeven falling from $81 to $59 in a single year, with a path to the high $40s, is the strongest structural argument in the entire release, and it received almost no attention. If it holds, it changes what a downside oil scenario does to this equity. It is the number to grade management against for the rest of the plan.

11. Braskem: From Absentee to Active, Without Consolidating the Debt

A new shareholders agreement has changed Petrobras's posture toward its 46% petrochemical stake, and management was blunt about the prior decade.

"Regis, what we have now is a willingness at Petrobras to work strongly on Braskem. If you look at the last 10 years, Petrobras was basically absent from Braskem. Our understanding is that this was not the right way. Braskem and Petrobras have very relevant synergies, especially with our refinement plants and the Brazilian gas consumption."
— Magda Chambriard, Chief Executive Officer

The CFO set the boundary: "I can say that we do not intend to consolidate debt. We will continue to be a minority in the company," with closing expected within 30 to 90 days. He also flagged the same war dynamic helping the petrochemical spread, noting the Middle East represents 25% of global petrochemical supplies.

Assessment: Engagement without consolidation is the right structure, and improving spreads reduce the probability that Braskem becomes a capital call. No figure was put on potential support, which leaves an unbounded, low-probability liability in the model.

Guidance & Outlook

Petrobras did not change any 2026 target. The CFO reiterated each one and framed production as tracking toward the upper end.

"Oil production reached 2.6 million barrels per day in the first quarter, therefore within the upper range of the target for the year. We're working to deliver production above the midpoint of the target, and the first quarter 2026 results indicate that we are on the right track. This is not a promise, but rather a pursuit of greater operational efficiency. We're maintaining our guidance while making every effort to produce even more."
— Fernando Melgarejo, Chief Financial and Investor Relations Officer

Implied ramp. Holding the 2.5 MMbpd midpoint with 2.583 already delivered implies the remaining three quarters can average 2.47 MMbpd and still hit target, which given April's 2.733 MMbpd record is close to arithmetically impossible on the downside. Production guidance is conservative and will be beaten. Capex and opex are the opposite: both are running three points above a straight-line quarter in the seasonally lightest period, with new projects being added to the budget mid-year.

Guidance style. Deliberately unrevised. Management chose not to raise anything into a $118 tape, which is the correct posture for a company whose credibility deficit is historically about capital discipline rather than about volumes. The cost of that posture is that the guidance now carries almost no information.

What the guidance does not include. No 2026 Brent planning assumption was given, despite the question being asked directly. No revenue, EBITDA or earnings guidance is provided, which is the company's long-standing practice.

Analyst Q&A Highlights

Domestic Fuel Pricing and the Risk of Shortages

The call opened on the question that dominates every Petrobras print when crude moves: whether the company will follow international prices at the Brazilian pump. Management's answer separated diesel, where a federal subsidy is now doing the work, from gasoline, where the binding constraint is competition from ethanol in a flex-fuel vehicle fleet rather than import parity.

Q: "I would like to hear your perspective on the downstream market. What can you tell us about the market and prices in a broader sense? Can you tell us about what the supply dynamics are like in Brazil right now? If you can tell us if there's any risk of shortages. Considering the recent price increases, how do you assess the need for adjustments in diesel and gasoline prices?"
— Leonardo Marcondes, Bank of America

A: "Our governance and price policy are not passing this volatility on. We are reducing the anxiety that we see in international prices when we set prices for Brazilian consumers, even though we're following the market in general, and we have a tendency to follow international prices. ... There will be a gas price increase, but we have to be sure that this market is still partly ours."
— Magda Chambriard, Chief Executive Officer

Assessment: A pre-announced gasoline increase conditioned on market share is a pricing policy with a political variable in it, and the answer said as much. Note also the disclosure that jet fuel price increases are being financed by Petrobras through extended payment terms into the second half, which is a working-capital cost that has not been quantified.

Subsidy Receivables and the Working-Capital Bridge

A recurring line of questioning on the call concerned how quickly the government subsidies convert to cash, and what happens to working capital as the subsidised volumes grow. Management confirmed the March tranche is in receivables and expected to collect within the second quarter, while the later tranches still require procedural completion.

Q: "I'd like to keep on discussing the fuels, and I'd like to dive into more details about the funding. In terms of working capital, this is possibly what stands out the most looking from an outside perspective. The first quarter had a slight effect due to the funding or subsidies."
— Rodrigo Almeida, BTG

A: "The impacts are reflected in the increased operational cash flow of the company and the free cash flow that we'll be seeing in the next few days, much closer to the current market prices, not paid by the end customers. The end customers are being protected as a result of the efforts made by the government. Part of these revenues come from the end consumers, and part of them come from the government."
— Fernando Melgarejo, Chief Financial and Investor Relations Officer

Assessment: The clearest statement on the call that Petrobras's realised domestic price is now a two-payer construct. The answer was forthcoming on mechanism and silent on magnitude; no cumulative receivable balance was given.

Whether a Stronger Oil Scenario Reopens the Capital Budget

The most substantive challenge of the session asked whether a plan built for a materially weaker oil price should now be revised upward on capex. Management's answer confirmed that projects are indeed being pulled into the budget, while insisting the decision rule remains long-term asset resilience rather than the spot price.

Q: "My question, to try to summarize it, is basically related to CapEx. What we should think about in terms of CapEx and if there should be an upside in terms of the numbers we've been working with given the new oil scenario."
— Gabriel Coelho Barra, Citi

A: "We still see a very volatile Brent price. We do believe that these prices will increase between now and the end of the year. This will bring about additional revenues in the short term. The decision to include new investments do not involve only a short-term perspective. Rather, it's a long-term perspective, and it involves identifying the resilience of the assets. Nothing has changed in terms of governance."
— Fernando Melgarejo, Chief Financial and Investor Relations Officer

Assessment: Management said "nothing has changed" and then described two platforms moving from outside the base budget to inside it. The governance process is intact; the envelope is not fixed. Investors should assume capex ends 2026 above the plan-tracking figure.

Course Correction and the Second-Half Oil Assumption

Asked directly what oil scenario the company is planning against for the second half, management answered with a breakeven rather than a price deck, then moved immediately to the cash hierarchy.

Q: "If you can tell us a little bit more about how much course correction you've been talking about, how frequently does the company talk about this or actually do it when necessary? What oil scenarios have you been working with for the second half of the year?"
— Tasso Vasconcellos, UBS

A: "The company has been getting prepared to work with a Brent balance of $59. This is what we foresee in the company regardless of our future Brent prices. ... The second point is that we are directing additional resources that we might have this year to reduce our debt to converge towards $65 billion as quick as we can or even below it."
— Fernando Melgarejo, Chief Financial and Investor Relations Officer

Assessment: The question about a second-half price assumption was not answered, deliberately and defensibly. The substitution of a breakeven for a forecast is analytically more useful than the forecast would have been, and it is the disclosure most worth carrying into the model.

Diesel Supply Levers and the Import Requirement

With utilization at record levels, the question turned to whether the system can carry the seasonally heavy second half without imports. The answer was candid: it cannot, and June is the inflection.

Q: "We can see that Petrobras is doing its part trying to supply the most it can to the market with refinery utilization reaching record levels. What do you think will happen in the future? What can you tell us about other levers to help supply the market with sporadic imports?"
— Rodolfo Angele, JPMorgan

A: "We believe that probably in the second half of the year, we will need to import diesel. In June already, in the second half of the year, without a doubt, we'll require diesel imports since that's usually when harvests happen and that has a higher demand. ... We're producing an additional 100,000 barrels of diesel with this increase in the utilization factor and the expansion of RNEST."
— Angélica Laureano, Executive Director, Logistics and Commercialization

Assessment: An honest answer that cuts against the self-sufficiency narrative in the prepared remarks. Second-half imports at post-Hormuz product prices are a margin headwind, mitigated by the CEO's separate statement that the subsidy covers imported barrels. That mitigation is a policy assumption, not a contract.

Braskem's Governance Reset and the Debt Question

The petrochemical stake drew the most detailed strategic answer of the call, combining a governance narrative from the CEO with a hard boundary from the CFO on the balance sheet.

Q: "This might be a crucial moment in which Braskem was moving towards a debt restructuring, at the same time, petrochemical spreads improved significantly since March. My question is, what changes with this new role for Petrobras? Does Braskem still require debt restructuring? Is there really a greater spread level?"
— Regis Cardoso, XP

A: "Right now, the company is in a transition. After signing the agreement, without the closing, we are already taking greater action. ... I can say that we do not intend to consolidate debt. We will continue to be a minority in the company."
— Fernando Melgarejo, Chief Financial and Investor Relations Officer

Assessment: The restructuring question was not answered. Management described improved spreads and an active posture without saying whether the balance sheet still requires repair, which is the only part of the question that matters to a Petrobras shareholder.

International Expansion: Mexico and Venezuela Against the Equatorial Margin

An attempt to size the international ambition in dollars was politely refused, and management drew a clear hierarchy between a near-term drilling programme and a set of aspirations.

Q: "I would like to get a little bit more color about your appetite for Mexico and Venezuela. If you can compare this with the equatorial margin. I'd just like to get an understanding if, for example, Venezuela and Mexico would be $1 billion or $5 billion in the next 2 years or the next 5 years."
— Lilyanna Yang, HSBC

A: "Like Sylvia said a short while ago, we are about 1,000 meters from our goal in the equatorial margin. That is our main goal, the first goal in our explorations. ... So far, all we've done is visit the Mexican presidency. There's still a long road ahead before we can quantify any kinds of investments in the Gulf of Mexico. ... Venezuela is a similar case. ... Right now, we still have it just as a wish list item."
— Magda Chambriard, Chief Executive Officer

Assessment: The right answer, and a reassuring one. Naming Mexico and Venezuela as wish-list items rather than committed capital removes the most obvious governance concern raised by the Mexico delegation headlines. The Equatorial Margin remains the only international item with a near-term catalyst attached.

Extraordinary Dividends Versus Deleveraging

The final exchange was the one the equity most needed answered: whether a cash flow running above the policy formula produces a special distribution this year. It does not, and the reason given was volatility rather than commitment.

A: "This year, the situation is still pretty cloudy to allow us to say that there will be a surplus that will allow us to pay extraordinary dividends. Right now, I can tell you that the possibilities are quite low so far. As Magda said, we've seen the Brent go from 110 to 90 overnight. Twenty dollars of volatility over the course of one day does not make us feel secure enough to make any decisions to distribute dividends."
— Fernando Melgarejo, Chief Financial and Investor Relations Officer

Assessment: The single most price-relevant statement on the call, and it came in the last five minutes. A shareholder base that owns this ADR for the distribution has just been told that the biggest oil price move in years will not produce an extraordinary one, with a review deferred to year-end. That is the strongest argument against paying up for the stock here.

What They're NOT Saying

1. The size of the export backlog in dollars. Roughly 80,000 bpd was disclosed as a volume. No price assumption, no revenue estimate and no confirmation that it clears entirely within 2Q26.
2. The cumulative subsidy receivable balance. Only the R$740M recognised in the quarter's results was quantified. The total amount owed by the federal government across the diesel, imported-diesel and LPG programmes was never stated, and the collection schedule beyond "within this quarter" was left open.
3. Realised prices and lifting cost. Neither appeared in the prepared remarks and neither was asked about. For a company whose entire quarter turned on the gap between screen prices and realisations, the absence of a per-barrel realisation bridge is a conspicuous gap.
4. The second-half Brent planning assumption. Asked explicitly. Answered with a breakeven instead. Management chose not to disclose what price the budget now assumes, which also means the $16.9B capex and $20.2B opex figures cannot be stress-tested by an outsider.
5. The capex cost of the projects being added. SEAP I and II were described by capacity, in barrels and cubic metres, with no capital figure and no revision to the annual envelope they were just moved inside.
6. Any framework for what triggers an extraordinary dividend. "Quite low" this year, reviewed at year-end. No surplus threshold, no leverage trigger, no timing commitment.
7. Whether Braskem still needs a debt restructuring. Asked directly. The answer covered governance, spreads and the intention not to consolidate, and skipped the restructuring question entirely.
8. The jet fuel financing cost. The CEO disclosed that Petrobras extended payment deadlines and diluted jet fuel price increases into the second half, describing it as "financing higher QAV prices." No figure was attached to that receivable either.

Market Reaction

• Pre-print setup: The ADR closed at $20.75 on May 11, the day the results were furnished after the Brazilian close. It entered the print up 75.1% year to date from $11.85 at the end of 2025 and up 75.8% over the trailing twelve months, against a 52-week closing range of $11.11 to $22.03. The S&P 500 was up 8.3% year to date over the same stretch. The stock had cooled into the event, down 3.5% over the trailing 30 days from $21.51 on April 10.
• Next-day session: PBR opened at $20.28 on May 12, a gap down of 2.3%, traded a range of $20.16 to $20.70, and closed at $20.50, down 1.2% or $0.25 on the day. The S&P 500 fell 0.2% in the same session.
• Volume: 22.6 million shares against a 25.6 million 30-day average, or 0.9 times normal. Turnover was unremarkable.
• Call timing: The results were furnished after the close on May 11 and the webcast was held on the morning of May 12, so the reaction session incorporates both the print and the call.

A double-digit revenue miss and a quarter-sized shortfall against the recurring earnings consensus produced a 1.2% decline on below-average volume. That is not indifference; it is a market that had already read the same calendar management described. The March Brent move was public information, the export-pricing convention is well understood by the Brazilian analyst community, and the shape of the miss was largely anticipated by anyone who had modelled the lag.

The more interesting signal is what the muted reaction implies about positioning. A stock up 75% year to date that absorbs a miss without breaking is a stock whose marginal holder is looking through the print to the second quarter. That cuts both ways. The setup that cushioned the downside on May 12 is also the setup that limits the upside when 2Q26 delivers the catch-up, because the catch-up is now the consensus expectation rather than a surprise.

What the tape did not reward was the operational record. Production of 3.23 MMboed, a six-point utilization jump and an April monthly record of 2.733 MMbpd were all in the release, and none of it moved the price. The market is pricing this equity off Brent and off Brasilia, not off the barrel count, which is a fair reading of where the earnings variance actually comes from.

Street Perspective

Debate: Is the Miss a Timing Artifact or a Structural Pass-Through Problem?

Bull view: The bull case on the Street is that this is pure calendar. Cargoes priced in February shipped in March, roughly 80,000 bpd sat in backlog, and the entire export book reprices in the second quarter at a much higher strip. Nothing about the business changed; only the recognition date did.

Bear view: The bear camp contends that the pattern is not an accident of one quarter. Petrobras's realisations lag on the way up because of trade-date conventions, and its domestic prices lag on the way up because of policy. The company therefore captures crude rallies late and partially, while absorbing declines promptly. On that reading the 1Q26 gap is a permanent structural discount, not a deferral.

Our take: The bulls are right about this quarter and the bears are right about the franchise. The 2Q26 catch-up will happen and will be large. But a business that cannot monetise a 51% one-month move in its primary commodity within the quarter it occurs should carry a lower multiple on spot earnings than a peer that can, and that is a permanent feature rather than a first-quarter accident.

Debate: Where Does the Windfall Go?

Bull view: The optimists argue the 45%-of-free-cash-flow policy is mechanical, so a bigger second quarter automatically produces a bigger distribution, with the deleveraging to $67B providing a second leg of equity value creation on top.

Bear view: Skeptics point at what management actually said. Investment comes first, debt second, and shareholders third; projects previously outside base capex are being pulled in; and the CFO put the odds of an extraordinary distribution at "quite low" for the year. Gross debt rose in a record quarter, and free cash flow after lease repayments did not cover the distribution that was declared.

Our take: The bears have the better of this. The ordinary distribution will rise with free cash flow because the formula compels it, but the incremental dollar of a higher oil price has been explicitly earmarked for the drill bit and then the balance sheet. Anyone underwriting a step-change in total return through distributions in 2026 is arguing with the CFO's own words.

Debate: Is the Subsidy Architecture a Shield or a Dependency?

Bull view: A growing consensus view is that the subsidy is unambiguously positive. Petrobras keeps market share, protects the Brazilian consumer, avoids the political blowback that historically forced below-parity pricing, and gets paid by the treasury for the difference. The CEO stated plainly that the company is not taking losses.

Bear view: The other side notes that the compensation is a sovereign receivable with an administrative collection process, not a customer payment; that its continuation is a fiscal choice reviewed periodically; and that the mechanism has already begun consuming working capital. It converts a commodity margin into a claim on the Brazilian budget.

Our take: It is a shield today and a dependency structurally. The right way to hold it in a model is as a positive with a widening confidence interval: assume collection in the near term, and haircut the downstream margin in any scenario where Brent stays above $100 for several quarters and the fiscal cost compounds.

Debate: Does a 75% Year-to-Date Return Already Price the War?

Bull view: The bull case is that the stock is still cheap on any normalised measure, with a distribution yield in the mid single digits on the first-quarter declaration alone, and that the 2Q26 earnings jump has not yet been printed.

Bear view: The bears observe that the entire year-to-date move tracks the Brent move, that Brent's level is a function of the Strait of Hormuz remaining closed, and that the equity therefore carries a war premium it did not earn operationally. A negotiated reopening would compress both the commodity and the multiple at once.

Our take: This is the crux and it decides the rating. Petrobras has become, at $20.50, a levered expression of a geopolitical event with the Brazilian state holding a veto over how much of the upside reaches the income statement. The operational improvement is real and would justify a re-rating on its own over several years. It does not justify chasing the stock 75% into a print that missed.

Model Update & Valuation Framework

This is initiation, so the items below establish the starting parameterisation rather than revise a prior model.

Valuation framework. At $20.50 per ADS across the 6,444 million ADS-equivalent shares in note 26.5, the equity is capitalised at roughly $132B on a common-share-equivalent basis, before the discount at which the preferred line trades. Against that, annualising 1Q26 recurring net income of $4.5B gives roughly $18B, which lands the ADR near 7.3 times a run rate that management has told us understates second-quarter earnings power. The 1Q26 declaration of R$0.70097272 per share annualises to roughly a 5% distribution yield at the quarter's average exchange rate, before any step-up.

Valuation impact. Those are undemanding multiples on depressed inputs, and that is precisely the trap. The inputs are depressed because of a one-quarter timing effect that everybody can see, so the multiple is not a discount that a patient holder gets paid for. Our fair-value framework sits in the low $20s: the second-quarter catch-up is worth several dollars of earnings power, and the war premium embedded in the commodity is worth several dollars of risk against it. That combination is what a Hold looks like.

Thesis Scorecard Post-Earnings

This is first coverage, so the pillars below are established rather than graded against a prior quarter. Each carries the status it earned on this print, and each becomes the standing scorecard from next quarter forward.

Overall: Thesis established with the operational pillars confirmed and the capital-return pillar challenged on its first test. Petrobras is executing better than at any point in the last decade on the things engineers control, and the constraint has moved from the reservoir to the treasury and the ministry.

Action: Hold. Initiate a position on weakness toward the mid-teens or on evidence that the second-quarter cash actually reaches holders rather than the capital budget. The signposts for an upgrade are specific: collection of the subsidy receivables in full during 2Q26, gross debt printing below $70B at the half, and an ordinary distribution that steps up in line with the free cash flow formula. The signposts for a downgrade are equally specific: a negotiated reopening of the Strait of Hormuz, a 2026 capex figure revised above $21B, or a subsidy programme that lapses without a corresponding domestic price increase.