TTE: FY25 Deep Dive
FY25 revenue $182.3B (-6.8%) — net income $13.13B (-17%) on lower Brent realized prices. Hydrocarbon production +4% Q3. Q3 E&P adj net income $2.2B, integrated LNG cash flow $1.1B; Downstream $1.1B (+30%). FCF $10.81B; capital return $16.5B (div $8.5B + buyback $8.0B). $1.5B Q4 buyback authorized. ADR program terminated; ordinary shares trade NYSE from Dec 8, 2025. JPM upgraded N→OW; Scotiabank +$24 PT raise.
Key Takeaways
TotalEnergies closed fiscal 2025 (calendar year ended December 31, 2025) at $182.3 billion of revenue, down 6.8% YoY — reflecting lower Brent crude realized prices in 2025 vs 2024. Net income was $13.13 billion (-17% from $15.76B FY24); diluted EPS $5.78 (vs $6.69 FY24). Operating income $65.18B (margin recovery on cost optimization despite lower top line). The structural Q3 segment readout from FY25:
- Hydrocarbon production +4% Q3 QoQ with high-margin new projects contributing
- E&P adjusted net income $2.2B Q3 (+10% QoQ); cash flow $4B (+6% QoQ)
- Integrated LNG sales 10.4 Mt flat QoQ; cash flow $1.1B
- Integrated Power net generation +9% QoQ to 12.6 TWh; cash flow $0.6B
- Downstream adjusted NOI $1.1B Q3 (+30% QoQ on European refining margins); cash flow $1.7B (+11% QoQ)
Free cash flow was $10.81 billion (vs $15.95B FY24, -32% on lower commodity prices); capex $17.64B; net debt expanded modestly. Capital allocation: $8.45B in dividends + $8.03B in buybacks = $16.48B total return. Q4 2025 board authorized up to $1.5B additional share buyback. ADR program terminated; ordinary shares began trading on NYSE from December 8, 2025 — same structural shift as Novartis. Total debt $61.4B. Sell-side coverage in window: JPMorgan upgraded Neutral → Overweight on March 2 (no PT disclosed), Scotiabank $73 → $97 on April 22 (+$24, the largest PT raise), Piper Sandler $74 → $92 on March 12 (+$18). Consensus PT $94.50, range $92-$97. 3 analysts: 1 Buy / 2 Hold / 0 Sell.
Main business structure
TotalEnergies operates 4 main segments + corporate:
| Segment | Approx FY25 Cash Flow Share | Key Driver |
|---|---|---|
| Exploration & Production | ~50% | Brent + Henry Hub hydrocarbon production |
| Integrated LNG | ~15% | LNG offtake + sales globally |
| Integrated Power | ~5% | Renewables + gas-fired electricity generation |
| Refining & Chemicals (Downstream) | ~20% | European + global refining margins |
| Marketing & Services | ~10% | Service stations + commercial sales |
Exploration & Production (~50% of cash flow)
- Q3 FY25 hydrocarbon production +4% QoQ on new high-margin projects
- E&P Q3 adjusted net income $2.2B (+10% QoQ); cash flow $4B (+6% QoQ)
- Major upstream geographies: Norway (Greater Ekofisk), West Africa, Middle East, Russia (legacy), Brazil
Integrated LNG (~15%)
- Q3 sales 10.4 Mt (flat QoQ); cash flow $1.1B
- Long-term offtake from Mozambique LNG, Ichthys (Australia), Cameron LNG (US), Yamal LNG (Russia)
- Diversified portfolio supports stable cash flow through commodity cycles
Integrated Power (~5%, but growing)
- Q3 net generation +9% QoQ to 12.6 TWh
- Mix of renewable (solar + wind, growing) and gas-fired (legacy + grid stability)
- Strategic growth area: power demand growth + renewables transition
Refining & Chemicals (~20%)
- Q3 adjusted NOI $1.1B (+30% QoQ on improved European refining margins)
- Cash flow $1.7B (+11% QoQ)
- Refining + petrochemicals across Europe + US
Marketing & Services (~10%)
- ~16,000 service stations globally
- Lower-margin retail / commercial sales
- Cash-generative + counter-cyclical
Strategic Moves FY25
- ADR program terminated: ordinary shares began trading NYSE from December 8, 2025
- Q4 $1.5B share buyback authorization (incremental)
- Two-pillar strategy: (1) Hydrocarbons (cash generation), (2) Integrated Power (transition growth)
- Continued investment in low-carbon LNG + renewables capex
Geographic mix. Production exposure: Africa ~25%, Middle East ~20%, Europe ~20%, Americas ~20%, Asia ~10%, Other ~5%.
Customer concentration. Wholesale + retail customers globally; no single 10%+.
Scale anchors. ~100,000 employees globally. ~3.0 MMBOE/d hydrocarbon production. Operations in 130+ countries.
Key core metrics (3-year trend)
1. Revenue + commodity-cycle exposure
| FY23 | FY24 | FY25 | |
|---|---|---|---|
| Revenue ($B) | 218.95 | 195.61 | 182.34 |
| YoY | — | -11% | -7% |
Continued revenue decline reflects lower Brent realized prices YoY (2024 averaged ~$83/bbl vs 2025 ~$70-75/bbl).
2. Earnings
| FY23 | FY24 | FY25 | |
|---|---|---|---|
| Operating income ($B) | 30.86 | 24.10 | 65.19 |
| Net income ($B) | 21.38 | 15.76 | 13.13 |
| Diluted EPS | $8.67 | $6.69 | $5.78 |
The FY25 operating income jump to $65B vs $24B FY24 reflects accounting reclassifications + asset gain accounting; net income better reflects underlying operating performance ($13.1B FY25 vs $15.8B FY24).
3. FCF + capital allocation
| FY23 | FY24 | FY25 | |
|---|---|---|---|
| OCF ($B) | 40.68 | 30.85 | 28.46 |
| Capex ($B) | 17.72 | 14.91 | 17.64 |
| FCF ($B) | 22.96 | 15.95 | 10.81 |
| Dividends ($B) | 7.52 | 7.72 | 8.45 |
| Buybacks ($B) | 9.17 | 8.00 | 8.03 |
| Total return ($B) | 16.69 | 15.71 | 16.48 |
| Total debt ($B) | 47.87 | 53.56 | 61.42 |
FCF compressed -32% YoY to $10.8B on lower commodity prices + modestly elevated capex. Total debt expanded ~$8B for capital allocation continuity. Capital return held ~$16.5B.
Market evaluation
Sell-side coverage (as of April 27, 2026). 3 covered analysts captured.
| Rating | Count |
|---|---|
| Buy / Outperform / Overweight | 1 |
| Hold / Sector Perform | 2 |
| Sell | 0 |
Price targets. Consensus $94.50, range $92-$97.
Recent analyst activity (Feb-April 2026):
- JPMorgan: upgraded Neutral → Overweight on March 2 (no PT disclosed) — the structural rating change in window
- Scotiabank: $73 → $97 on April 22 — Sector Perform maintained, +$24 PT raise (the largest), Street-high
- Piper Sandler: $74 → $92 on March 12 — Neutral maintained, +$18
The pattern: bullish PT direction across all 3 actions; JPM upgrade signals fresh institutional Buy-side engagement on the integrated business model + capital return profile + power transition optionality.
Buy-side positioning. TTE is a core European integrated oil major holding paired with XOM, CVX, SHEL, BP. The ADR-to-direct-NYSE shift makes the stock more accessible to US ETF/index buyers. Trades at discount to US majors on geographic / regulatory factor + slightly lower yield. Short interest below 1% of float.
FY25 corporate structure: integrated oil major + ADR-to-direct shift + capital return continuity
FY25 was a transition year for TotalEnergies — revenue down 7% on lower commodity prices, FCF -32% to $10.8B, but capital return held at $16.5B (div $8.45B + buyback $8.03B). The structural moves were significant: ADR program terminated with ordinary shares trading NYSE from Dec 8, 2025 (technical structure change for US investor accessibility); Q4 incremental $1.5B buyback authorization; Two-pillar strategy reaffirmed (Hydrocarbons + Integrated Power). The Street's response: JPM upgrade, +$24 Scotiabank PT raise, +$18 Piper raise — Street rerating to the integrated business model + capital return template. The Q1 FY26 earnings print this week is the proximate event for measuring continued production growth (Q3 +4% QoQ trajectory) + LNG cash flow + Downstream margin recovery + Integrated Power generation expansion.