TotalEnergies Q2 adjusted profit hits $6bn on high oil and refining margins

TotalEnergies SE (NYSE: TTE; Euronext Paris: TTE) reported second-quarter 2026 adjusted net income of $6.0 billion and cash flow from operations excluding working capital of $9.8 billion, up almost 15% quarter-on-quarter, in results released by the Paris-headquartered integrated energy group on July 23, 2026. First-half adjusted net income reached $11.4 billion, up 47% year-on-year, with adjusted earnings per share of $5.14 versus $3.41 a year earlier. The Board of Directors, chaired by Chief Executive Patrick Pouyanné, approved a second interim dividend of €0.90 per share for fiscal 2026, up 5.9%, and authorised the continuation of share buybacks of up to $1.5 billion for the third quarter. The central tension of the release is the interaction between a high commodity-price tailwind, tied to the Middle East conflict, and the direct production and lifting cost that same conflict has imposed through restricted access to the Strait of Hormuz.

How did TotalEnergies convert Middle East volatility into $9.8 billion of second-quarter cash flow rather than a shortfall?

The quarter benefited from an environment in which Brent crude averaged $103.8 per barrel, up 28% quarter-on-quarter and up 53% year-on-year, while the European Refining Margin Marker tracked $13.5 per barrel, compared with $4.7 a year earlier. The Title Transfer Facility gas benchmark averaged $15.6 per million British thermal units and the Japan Korea Marker averaged $17.5, both materially above the first quarter. Every operating segment except Integrated LNG expanded adjusted net operating income sequentially, with Refining and Chemicals rising 13% quarter-on-quarter to $1.8 billion, and Marketing and Services almost doubling to $500 million.

Cash flow of $9.8 billion was, in effect, the diversified integrated model doing its intended work. Exploration and Production captured the price uplift on liquids at the same time as downstream captured the margin expansion on refined products, while Marketing and Services benefited from a favourable European seasonality. Chief Financial Officer Jean-Pierre Sbraire noted on the results call that gas trading underperformed in the quarter because European prices fell rather than rose as positioned, but that the segment could rebound in the third quarter. That framing is important. The blend of segments produced a strong headline number even though at least one of them, LNG trading, went the wrong way.

Why does the 210 kboe/d Strait of Hormuz hit matter more than the headline production number suggests?

Company hydrocarbon production for the second quarter was 2,395 thousand barrels of oil equivalent per day, down 4% year-on-year and down 6% quarter-on-quarter. The four-percentage-point year-on-year decline is entirely a function of the conflict; excluding the impact, production would have grown by more than 4% year-on-year, driven by the ramp-up of the Mero-3, Mero-4 and Lapa SW projects in Brazil, Anchor and Ballymore in the United States, Begonia and Clov Phase 3 in Angola, and Mabruk in Libya.

The nuance that matters for the model is that TotalEnergies quantified the impact at an average 210 thousand barrels of oil equivalent per day over the second quarter, and warned that the third-quarter impact could sit between 5% and 10% of total company production. Beyond the shut-in barrels, Chief Executive Patrick Pouyanné flagged that lifting through the Strait of Hormuz had itself become difficult, meaning that even barrels produced in the region were not always being loaded on schedule. That distinction shows up directly in the results. The company noted that the average selling price of liquids rose only $17.9 per barrel quarter-on-quarter, against a $22.7 per barrel move in Brent, because a larger off-take schedule fell into the end of the quarter when the physical market was already bearish. In short, the price capture rate on realisations was compressed by the same choke point that is capping volumes.

What drove Exploration and Production’s $5.8 billion quarterly cash flow despite lower lifting volumes?

Exploration and Production posted adjusted net operating income of $3.2 billion, up 25% quarter-on-quarter, with cash flow from operations excluding working capital of $5.8 billion, up 27%. The segment carried the release. Upstream operating costs were held at $5 per barrel, and net investments for the segment fell 25% quarter-on-quarter to $1.9 billion after $1.4 billion of disposals, including the divestment of a non-operated interest in the Marjoram gas field in Malaysia.

Two portfolio actions stood out in the highlights. TotalEnergies entered the Bab Gas Cap onshore concession in Abu Dhabi with a 10% stake and, alongside partners in the United Arab Emirates, took a Final Investment Decision on the Umm Shaif Gas Cap project, targeting more than 600 million cubic feet per day of gas production by 2030 along with associated condensates. The company also signed a cooperation agreement with the Syrian Petroleum Company on offshore Block 3, and a separate framework with EGAS in Egypt covering offshore exploration opportunities. These are early-stage entries rather than reserves the market can capitalise today, but they signal that the company is still taking risk on new gas-weighted acreage in the Middle East and North Africa even as the region is currently costing it barrels.

How did Integrated LNG give back most of its first-quarter trading outperformance in a flat European gas market?

Integrated LNG adjusted net operating income was $807 million in the quarter, down 39% quarter-on-quarter, and cash flow from operations excluding working capital was $833 million, down 53%. TotalEnergies attributed the drop to underperformance in gas trading in a European market that was broadly flat to declining, versus a first quarter in which the segment had outperformed. Hydrocarbon production for LNG fell 9% quarter-on-quarter to 550 thousand barrels of oil equivalent per day, largely because of shut-in production in Qatar tied to the Middle East conflict.

Underneath the trading noise, the physical LNG portfolio kept moving. The ECA LNG plant on the Pacific coast of Mexico started up in early July, strengthening TotalEnergies’ exposure to Asian offtake and adding a route to market that does not depend on the Strait of Hormuz. The company also signed new long-term oil-indexed LNG supply agreements with Chugoku in Japan and Hangzhou Gas in China. Company guidance is that the average LNG selling price should track above $11.5 per million British thermal units in the third quarter, driven by the lag effect on oil-indexed formulas after the recent price move.

Why is TotalEnergies’ Refining and Chemicals segment now generating nearly five times last year’s adjusted net operating income?

Refining and Chemicals delivered adjusted net operating income of $1.8 billion in the second quarter, up 13% quarter-on-quarter, and $3.4 billion in the first half against $690 million in the first half of 2025. The European Refining Margin Marker averaged $12.4 per barrel across the first half, against $4.3 a year earlier. Refinery throughput was 1,426 thousand barrels per day, down 12% quarter-on-quarter, reflecting a deliberate shift towards distillate maximisation, a planned shutdown at Donges in France, an unplanned Port Arthur shutdown in the United States following a tropical storm, and a partial return at SATORP in Saudi Arabia which has been running at 70% of nominal capacity since May.

The point that will matter for the sustainability of the number is Pouyanné’s own description of global refining margins as sitting at historically high levels because of a combination that will not necessarily persist: unavailability of Russian refining capacity, disruption of Middle East supply to Asian refineries, and global inventories at historical lows. If any one of those legs relaxes, particularly the Middle East supply disruption, refining spreads could compress in the second half. Company guidance for third-quarter refinery utilisation is 80% to 85%, with SATORP expected to return to nominal capacity by the end of the third quarter.

How does the EPH portfolio and Kazakhstan Mirrny decision reshape TotalEnergies’ Integrated Power cash flow?

Integrated Power adjusted net operating income was $533 million, effectively flat quarter-on-quarter, but cash flow from operations excluding working capital jumped 26% to $721 million, supported by the contribution of the EPH portfolio of flexible power generation assets in the United Kingdom, Italy, the Netherlands and France, which closed on April 29, 2026. Gas flexible generation capacity moved from 7.0 gigawatts at the end of the first quarter to 12.2 gigawatts at the end of the second quarter, and total installed net capacity crossed 33.4 gigawatts. Chief Financial Officer Jean-Pierre Sbraire indicated that production activities including renewables and gas-fired plants contribute roughly 60% of Integrated Power cash flow, with marketing and trading activities contributing the remaining 40%.

The company also took Final Investment Decision on Mirrny in Kazakhstan, a 1 gigawatt onshore wind project with 600 megawatt-hours of batteries expected to produce approximately 100 terawatt-hours of renewable electricity over 25 years, and started construction on a 440 megawatt-peak solar plant in the Philippines aiming for commissioning at the end of 2027. The company simultaneously sold all distributed solar assets in seven European countries, and executed farm-down transactions on battery storage projects in Germany. The message from the disposals side is that TotalEnergies is willing to rotate out of assets that dilute segment returns to fund large-format projects with defined offtake economics.

What does a gearing ratio of 13.1% signal about capital allocation into the second half of 2026?

The gearing ratio fell to 13.1% at the end of the second quarter from 15.5% at the end of the first quarter and 17.9% a year earlier, on net debt down $3.3 billion during the quarter to $19.7 billion. Return on average capital employed rose to 13.9% for the twelve months to June 30, 2026, and return on equity to 15.9%, both improving versus the same measures at March 31, 2026 and June 30, 2025. First-half free cash flow after organic investments doubled to $9 billion.

The read is that TotalEnergies is walking down the balance sheet at the same time as it is walking up the dividend. Net investments for the first half were $7.9 billion, on track for annual guidance of $15 billion, but H1 acquisitions net of asset sales came in at negative $1.4 billion, meaning divestments exceeded acquisitions. Combined with the Q3 buyback authorisation of $1.5 billion, the direction of travel is that TotalEnergies is choosing distributions and deleveraging over inorganic growth in the current price environment.

How should investors weigh the €0.90 dividend hike and $1.5 billion Q3 buyback against production risk?

TotalEnergies repurchased 16.9 million shares in the second quarter for $1.5 billion, and 26.3 million shares in the first half for $2.25 billion. Combined H1 payout of dividends and buybacks reached a payout ratio of 33% of cash flow from operations excluding working capital, down from 54% in the first half of 2025, which suggests the company is retaining a larger share of cash flow this year, consistent with the deleveraging priority. The €0.90 second interim dividend for fiscal 2026, up 5.9%, is payable on January 5, 2027 in Europe and January 22, 2027 for U.S. register holders.

Investor reaction was positive on results day. TotalEnergies stock on Euronext Paris closed at €76.18 on July 23, 2026, up 2.54% on the session, trading in a €74.53 to €76.68 range on the day. Analyst positioning around the print includes Buy ratings from RBC Capital, UBS and Jefferies, an Outperform initiation from Mizuho, and Hold ratings from Berenberg among the recent notes tracked by TipRanks. The consensus average price target sits at around $80 for the ADR, with a high of $94 and a low of $53, spread that in itself reflects disagreement about how long the current commodity backdrop persists.

What are the specific execution tests for TotalEnergies over the remainder of 2026?

The third quarter will test three things at once. First, production. Company guidance is for third-quarter growth in line with the 3% annual target excluding conflict impact, but with a 5% to 10% Middle East reduction whose actual expression depends on Strait of Hormuz lifting access; that number is not in TotalEnergies’ control. Second, refining. The company needs SATORP to complete its return to nominal capacity by the end of the third quarter and refinery utilisation to sit in the 80% to 85% range for the segment to sustain a run rate consistent with the first-half print. Third, LNG trading. After a strong Q1 and a weak Q2, the segment enters the third quarter with company commentary that the position has since improved, but recovery is not confirmed until the September quarter delivers.

Beyond the quarter itself, the near-term catalysts already scheduled include the ECA LNG ramp on the Mexican Pacific coast, and the ramp on Anchor and Ballymore in the U.S. Gulf and Mero-4 offshore Brazil. The signing at the Pangea 5 supercomputer with Dell Technologies and NVIDIA, with 150 petaflops of computing power, is a longer-dated bet on the company’s ability to accelerate subsurface interpretation and reservoir management across the portfolio. It will not move a single quarter, but it is the kind of infrastructure spend that separates majors that continue to renew their reserve base from those that do not.

What should investors track next for TotalEnergies as the Middle East impact and refining tailwind interact through Q3?

• Second-quarter adjusted net income of $6.0 billion and cash flow of $9.8 billion, up almost 15% quarter-on-quarter, was delivered on Brent averaging $103.8 per barrel and the European Refining Margin Marker at $13.5 per barrel, both materially above prior periods.
• Total company production of 2,395 thousand barrels of oil equivalent per day was down 4% year-on-year purely because of the Middle East conflict, and would have grown more than 4% year-on-year excluding that impact.
• The 210 thousand barrels of oil equivalent per day of Middle East production losses in the second quarter is now the single most important number in the outlook, with company guidance for the third-quarter impact at 5% to 10% of total production dependent on Strait of Hormuz access.
• Integrated LNG adjusted net operating income fell 39% quarter-on-quarter to $807 million because gas trading underperformed a flat European market after outperforming in the first quarter; the company signalled scope for recovery in the third quarter but has not yet delivered it.
• Refining and Chemicals adjusted net operating income of $1.8 billion in the second quarter and $3.4 billion in the first half reflects a refining margin environment Chief Executive Patrick Pouyanné characterised as historically high, with three specific drivers, unavailable Russian capacity, Middle East to Asia supply disruption and global inventories at historical lows, each of which is a candidate to fade.
• Integrated Power cash flow of $721 million was materially supported by the EPH acquisition closed on April 29, 2026, which lifted gas flexible capacity from 7.0 to 12.2 gigawatts, and by Final Investment Decision on the 1 gigawatt Mirrny wind and battery project in Kazakhstan.
• Gearing fell to 13.1% from 15.5% at the end of the first quarter and 17.9% a year earlier on a $3.3 billion net debt reduction, with the H1 payout ratio at 33% versus 54% a year earlier, meaning TotalEnergies is retaining more cash flow and prioritising deleveraging over inorganic growth.
• The second interim dividend of €0.90 per share, up 5.9%, plus $1.5 billion of third-quarter buybacks authorised on top of $2.25 billion executed in the first half, sets the shareholder distribution trajectory for the second half.
• The most credible near-term thesis-strengthener would be a recovery in Integrated LNG trading in the third quarter combined with an on-schedule return of SATORP to nominal capacity by quarter end; the most credible thesis-weakener would be a further worsening of Strait of Hormuz lifting access that lifts the Middle East production impact toward or above the top of the 5% to 10% guidance band while refining margins simultaneously normalise.