With a combined revenue of $21 trillion and $2.1 trillion in profits, the 2026 Fortune 500 is the definitive list of America's largest companies.

Fortune 500

Almost $20 trillion in revenue—and a record-breaking $1.87 trillion in profits. Introducing the 2025 Fortune 500, the definitive list of the biggest companies in America.

Industries included in the sector are mining, oil and gas exploration and services, pipelines, refining, and utilities.

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The Fortune 500, in its 70th year in 2024, ranks the biggest U.S. companies by revenue.

The corporations on our annual list of the world’s largest companies delivered a record $41 trillion in aggregate revenues.

Fortune Global 500

The Fortune 500, in its 69th year in 2023, ranks the biggest U.S. companies by revenue.

This year’s Fortune 500 marks the 68th running of the list.

This year’s Fortune 500 marks the 67th running of the list.

F500-2021-328-Cheniere Energy

Producing a specialized liquid form of natural gas, the company became the first U.S.-based company to export liquefied natural gas in 2016.

This year's Fortune 500 marks the 66th running of the list.

F500-2020-329-Cheniere-Energy

Headquartered in Houston, Cheniere is one of the leading producers of liquefied natural gas in the U.S.

This year's Fortune 500 marks the 65th running of the list.

This year's Fortune 500 marks the 64th running of the list.

Key Financials (last Fiscal Year)

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Cheniere Energy is the largest producer of liquefied natural gas in the U.S. and the second-largest LNG operator in the world. The company buys natural gas, processes it into LNG, and then sells it. The company also owns and operates the Sabine Pass LNG terminal in Cameron Parish, La., and the Corpus Christi LNG terminal in south Texas, as well as key pipelines. Cheniere’s LNG has reached more than 40 markets in five continents.

Q2 2026

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Q3 2024

Cheniere Energy (LNG): Company Profile, Stock Price, News, Rankings

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Cheniere Energy

cheniere energy

Good day and welcome to the third quarter 2025 Cheniere Energy earnings call and webcast. Today's conference is being recorded. At this time, I would like to turn the conference over to Randy Bhatia, Vice President of Investor Relations and Communications. Please go ahead.

Thank you. Operator, good morning everyone and welcome to Cheniere's third quarter 2025 earnings conference call. The slide presentation and access to the webcast for today's call are available at cheniere.com. Joining me this morning are Jack Fusco, Cheniere's President and CEO, Anatol Feygin, Executive Vice President and Chief Commercial Officer, and Zach Davis, Executive Vice President and CFO. Before we begin, I would like to remind all listeners that our remarks, including answers to your questions, may contain forward-looking statements and actual results could differ materially from what is described in these statements. Slide 2 of our presentation contains a discussion of those forward-looking statements and associated risks. In addition, we may include references to certain non-GAAP financial measures such as consolidated adjusted EBITDA and distributable cash flow.

A reconciliation of these measures to the most comparable GAAP financial measure can be found in the appendix to the slide presentation. As part of our discussion of Cheniere's results, today's call may also include selected financial information and results for Cheniere Energy Partners, LP or CQP. We do not intend to cover CQP's results separately from those of Cheniere Energy, Inc. The call agenda is shown on slide 3. Jack will begin with operating and financial highlights, Anatol will then provide an update on the LNG market, and Zach will review our financial results, 2025 guidance, and initial outlook for 2026. After prepared remarks, we will open the call for Q&A. I will now turn the call over to Jack Fusco, Cheniere's President and CEO.

Thank you, Randy. Good morning, everyone. Thanks for joining us today. As we review our results from the third quarter of 2025, I think we can all agree that this year has been one of the more challenging, with geopolitical unrest, rising costs and insufficient supply chains, tariffs, and now a government shutdown. My focus has been to lead Cheniere by putting our heads down, driving our growth strategy forward, continuing to deliver on operational excellence, executing on construction management, and implementing our capital allocation program. The third quarter of 2025 was once again marked by many key successes. Across our entire business, we made significant progress on the expansion of Corpus Christi Stage 3.

We progressed our development plans for engineering and commercialization of our expansion at Sabine Pass, all while continuing to achieve operational milestones, solidifying our reputation as a reliable supplier and partner to our global customer portfolio. The third quarter also gave us an opportunity to invest meaningfully back into ourselves with our share repurchase program for the benefit of all Cheniere stakeholders in the LNG market. Events and data points on both the supply side and demand side of the equation continue to fuel noise and volatility, but Cheniere's disciplined approach and our highly contracted business profile enable us to reliably deliver visible, predictable results in line with our previously issued forecast. We're very pleased to announce this morning that substantial completion of the third train of Corpus Christi Stage 3 has been achieved, an acceleration of our forecasted timeline from only a few months ago.

I'll have more to say on Stage 3 in a few minutes, including on a recently improved timeline on Train 4. Please turn now to slide five, where I highlight our key results and accomplishments for the third quarter of 2025. In the third quarter, we generated consolidated adjusted EBITDA of approximately $1.6 billion, distributable cash flow of approximately $1.6 billion, and net income of approximately $1 billion. Today, we are reconfirming our full year 2025 guidance range of $6.6 to $7 billion in consolidated adjusted EBITDA, and we are raising our distributable cash flow guidance range from $4.4 to $4.8 billion to $4.8 to $5.2 billion. Zach will provide more detail later on this call on our financial results, but the guidance increase related to our DCF outlook is being driven by a discrete IRS rule change related to the Corporate Alternative Minimum Tax.

Our guidance continues to be supported by the high degree of visibility and certainty our highly contracted platform affords, and we remain on track to deliver financial results within these ranges. During the third quarter, we produced and exported 163 cargoes of LNG from our facilities, which included the 3,000th LNG cargo produced at Sabine Pass. I'd like to recognize and congratulate our production and shipping teams at Sabine Pass on this milestone achievement, an incredible accomplishment less than 10 years since the first cargo was produced and exported from our facility. Across both facilities, we achieved production levels this year that are within our financial forecast while successfully navigating some operational challenges primarily driven by external factors such as variability in natural gas quality.

Structural shifts in the basin mix of domestic gas production attributed to new gas transportation infrastructure have made slight but noticeable changes in the composition of some feed gas we receive at our terminals. This requires our operating staff to make real-time adjustments to our liquefaction processes like solvent injections or defrost to clean heat exchangers, or adjusting our operating modes and maintenance activities to adapt to those changes. I'm extremely proud of the teams at both facilities for working safely and collaboratively to address these variables, develop long-term solutions to address feed gas composition in order to maximize sustainable, reliable production and enable us to deliver LNG volumes and financial results within our guided ranges. Looking ahead, the preliminary production forecast for 2026 has recently been completed and aided by the startup of the remaining trains at Corpus Christi Stage 3.

We expect 2026 to be another record year for LNG production. Our production forecast for 2026 accounts for the impact of strategically planned maintenance, including certain downtimes designed to deploy engineering solutions at both facilities to bolster long-term production reliability and build additional resilience to those external forces which can create production variability. With that said, with three mid scale trains now commercially operable and together with the remaining four Stage 3 trains and no prolonged major maintenance planned, we're looking forward to 2026 being our first year of producing over 50 million tons. During the third quarter, we continue to make excellent progress on our Comprehensive Capital Allocation plan, deploying approximately $1.8 billion across the pillars of our program. We funded approximately $600 million in growth CapEx, primarily across Corpus Christi Stage 3 and mid scale trains 8 and 9.

We paid approximately $110 million in dividends, and we repaid approximately $50 million in long term debt. The balance of the capital deployed was under a share repurchase plan, which was able to take further advantage of the value present in the shares during the quarter and bought back approximately 4.4 million shares for just over $1 billion, the second highest quarterly amount we have deployed repurchasing shares to date. Please turn to slide 6 where I'll update you on the progress of Corpus Christi Stage 3. I'm very proud of the progress we have made and continue to make executing all phases of this project. As total project completion on Stage 3 reached over 90% last month, execution remains on accelerated schedule, and as I mentioned earlier, we reached substantial completion on Train 3 ahead of our previous forecast.

Together with Bechtel Energy, we are achieving construction and commissioning milestones with the benefit of lessons learned on the first trains of the project. In fact, we reached a single day LNG production record last week of approximately 7.5 TBTU of LNG with Train 3 now operating. Similar to the commissioning timeline improvement we saw in Train 2, Train 3 went from first LNG to substantial completion in just 38 days. This is in contrast to the 77 days on the first train and evidence of the acceleration resulting from experience and knowledge transfer across trains. Of course, our long term partnership with Bechtel Energy. Train 4 is benefiting as well, and those that follow us closely have surely seen the regulatory approvals we've been receiving relating to the startup of that train.

On our previous call, my expectation was that we would have Train 4 in commissioning by the end of the year. However, we're bringing forward our timeline by over a month. With Train 4 now expected to produce first LNG very soon and is on track for substantial completion by the end of this year, we continue to forecast substantial completion of Trains 5 through 7 next year. Current key activities across those trains include the last few % of concrete and structural steel and the installation of above ground piping. As for the cadence of substantial completion for Trains 5, 6, and 7 next year, we expect those to occur in the spring, summer, and fall respectively, after Train 4 becomes commercially operable this winter.

On the mid scale Trains 8 and 9, a debottlenecking project, full notice to proceed was issued to Bechtel Energy in June and it has hit the ground running quite literally as the first ground pile was installed during the quarter. The bulk of the activity thus far has been on engineering and procurement as well as mobilization and site preparation. We're extremely excited about this project economics and timeline benefiting from all the work that's been done on Stage 3, and I look forward to updating you all on the safe execution and achievement of the milestones as we move into construction.

In the highly competitive market that we are in, continued demonstration of construction execution and timely delivery on customer commitments is a meaningful differentiator and significant competitive advantage, especially as we seek to further expand our footprint with more accretive brownfield growth at both sites that never compromises on our contracted return targets for investments. I'm extremely proud of these elements that have come to exemplify the Cheniere standard, which we are all committed to upholding across all aspects of our business for the benefit of all Cheniere shareholders. With that, I'll now hand it over to Anatol to discuss the LNG market. Thank you all again for your continued support of Cheniere.

Thanks Jack and good morning everyone. Please turn to Slide 8. Global LNG demand in 3Q25 was once again underpinned by European imports amid continued softness in Asia, resulting in price differentials that incentivized the flow of U.S. cargoes to Europe throughout the quarter. Unlike earlier in the year when geopolitical events drove volatility in global gas prices, both the JKM and TTF benchmarks remained largely range bound during the third quarter as compared to both 2Q25 and 3Q24. Despite an increase in LNG supply as new liquefaction capacity comes online, and in light of the relative moderation of Middle Eastern tensions that caused gas prices to increase late in the second quarter, global benchmarks remained relatively flat in the third. Monthly price settlements during the quarter averaged $12.50 an MMBtu for JKM and $11.27 an MMBtu for TTF, both relatively unchanged year on year.

This is a clear indication the market remains somewhat tight throughout the first half of 2025 and into the third quarter amid lower Russian gas deliveries year on year and much higher European underground storage injection requirements. This dynamic persisted into the third quarter despite an increase in global LNG supply and more moderate Asian LNG demand, which were unable to offset structural decreases in Russian piped gas and meaningfully higher European injections as compared to 2024. Ultimately, these dynamics provide a floor for global gas prices in the third quarter and maintaining price levels throughout the quarter, which contributed to muted price sensitive Asian demand. Aside from a temporary uptick in August driven by early restocking in the near to medium term, we broadly expect spot LNG prices to moderate as global balances begin to loosen in the upcoming period as additional liquefaction capacity comes online.

As we've discussed previously, we expect the market tightness of the past few years to moderate, with global prices becoming less sensitive to episodic price disruptions and volatility that stems from a delicately balanced market with minimal spare LNG capacity. We expect a significant portion of expected increases in liquefaction capacity to come from the U.S. highlighting the importance of U.S. LNG in maintaining global gas balances, and we expect this incremental supply will translate to a more stable pricing environment and serve to catalyze demand from price sensitive markets. Let's turn to the next page to address the regional dynamics in some detail. Europe's LNG imports continued to increase year on year in the third quarter, maintaining its call on U.S. cargoes away from Asia despite a period of stronger competition in August driven by early restocking in that market.

With regards to piped gas volumes, residual Russian pipe volumes flowing into Europe were 3.4 bcm, or a 43% decrease year on year during the quarter as other sources of pipe volumes from Norway, North Africa, and Azerbaijan were marginally higher in aggregate. Meanwhile, the continent entered the third quarter with a 20 bcm deficit in gas storage versus last year, driving stronger storage injections. As of the third quarter, storage injections have reduced that deficit to 13 bcm, or the equivalent of about 130 LNG cargoes, leaving European balances moderately tighter than we have seen in recent years, especially in light of a cooler than usual autumn, weaker hydropower output, and a potentially cooler winter forecast. Conversely, LNG imports into Asia remained subdued, declining 4% year on year during the third quarter and 6% 2025 year to date.

Softer gas demand across key markets in Asia, including China and India as well as other regions, resulted in aggregate LNG declines in 1H25, reversing the growth seen in 2024. This moderation in gas demand continued to filter into the LNG market in the third quarter despite the beginning of a demand rebound in China, which can be seen in the lower middle chart. Overall gas demand in China increased by 4.6 bcm from January through August, with much of that increased demand realized in recent months. While that pace of gas demand growth in China remains more measured, overall industrial demand has improved and gas-fired power generation has increased through August, gaining support from an 8 gigawatt increase in gas generation capacity in the first half of the year.

Against that backdrop, Chinese domestic gas production increased nearly 10 bcm and Russian piped imports increased 6.3 bcm in the corresponding period from January to August. This dynamic of increased domestic production and increased pipe gas volumes reduced the call on LNG imports in China, which declined 11% year on year or 2 million tons in the third quarter and 19% year on year or 11 million tons year to date as compared to 2024 when persistent heat waves in South and Southeast Asia drove a surge in LNG imports. Gas demand in the region has moderated year to date. Milder weather this summer, along with stronger hydroelectric power generation and lower electricity demand overall, drove gas power generation demand to decline by 19% in India in the first eight months of the year.

India led the South and Southeast Asian region's declines in LNG imports with a demand decline of 2 million tons year to date, and 0.7 million tons of this decline occurring in the third quarter. As the European call on LNG to replenish gas inventories ahead of winter remains strong and prices remain at current levels, we expect LNG demand growth in Asia to remain moderate in the near term. However, as discussed, we expect these dynamics to reverse in the medium term as new supply enters the market over the coming quarters, with significant implications for market balances moving forward. Within this context, we expect continued long-term LNG and natural gas adoption throughout Asia as demonstrated by forecast infrastructure growth in the region. Considering the region as a whole, gas-fired power generation capacity is expected to reach approximately 830 gigawatts by 2040.

That's an increase of over 70% from 2024, with regas capacity expected to reach over 1,000 million tons by 2040, a more than 50% increase from 2024. Let's turn to the next page to further address our outlook on LNG market balances. With a significant amount of liquefaction capacity forecast to come online over the next few years across the globe, the LNG market is entering a period of significant supply growth. This long-expected supply cycle is beginning to tangibly come to fruition as our Corpus Christi Stage 3 project has started to come online alongside other North American LNG projects both along the Gulf Coast and in Canada, and new capacity from Qatar is expected to enter the market later in the decade. We expect the global LNG market will add an average of 35 million tons of liquefaction capacity annually from 2025 through 2030.

This significant supply growth represents an annual CAGR of approximately 7% from 2025 through 2030. Despite incremental supply of approximately 30 to 40 million tons per annum expected in 2026, we continue to believe that latent price-sensitive LNG demand, particularly in Asia, will stand ready to absorb this additional supply efficiently. We expect a return to stronger growth in Asian LNG demand as the availability and affordability of LNG increases, catalyzing price-sensitive demand. The multi-year period of elevated prices we have experienced represents a clear signal that the market requires additional LNG supply, and we ultimately view a moderation in global LNG prices as favorable, necessary perhaps for meaningful long-term adoption of natural gas as a primary energy source and for investment in gas and LNG infrastructure across both developed and developing regions.

The forward curve currently indicates 2026 Asian spot LNG prices in the $11 range, which is supported by generally strong consensus from key market researchers that anchors around $10 to $11 price levels. With forecasted prices set to moderate later in the decade aided by new supply, we expect 2026 to represent the beginning of a pivot to more normalized spot LNG prices in the region. Even at the lower end of this price outlook, we expect U.S. LNG exports to continue unabated and do not expect any meaningful curtailments of U.S. LNG volumes. Ultimately, we view LNG supply additions as a moderating force on the global LNG market, and we expect this increased supply to invigorate demand as LNG becomes increasingly available and affordable, especially in price-sensitive and developing economies.

In developed markets, this period of increased supply would represent a welcome change for consumers following the current multi-year period of elevated prices following the energy crisis in Europe. In the context of this period of shifting market dynamics and increased LNG supply, our highly contracted business model insulates us from near- to mid-term market volatility while providing our customers destination-flexible volumes that enable them to navigate an evolving global LNG market as well as their own demand and consumption needs. At Cheniere, we will continue to maintain our disciplined approach to sanctioning new liquefaction capacity under long-term contracts and with high visibility into future cash flows as we enter this new period in the global LNG market. With that, I'll turn the call over to Zach to review our financial results and guidance.

Thanks Anatol and good morning everyone. I'm pleased to be here today to review our third quarter 2025 results and key financial accomplishments. Our financial guidance ranges for 2025 and our preliminary outlook for 2026 LNG volumes turn to Slide 12. For the third quarter 2025, we generated net income of approximately $1.05 billion, consolidated adjusted EBITDA of approximately $1.6 billion, and distributable cash flow of approximately $1.6 billion. Compared to the third quarter of 2024, our 2025 results reflect higher total volumes of LNG produced across our platform, primarily as a result of the substantial completion of mid scale Trains 1 and 2 at Corpus Christi Stage 3 and higher total margins as a result of increased cargoes that CMI was able to sell in the spot market opportunistically earlier this year.

As Jack mentioned, we navigated some operational volatility this quarter primarily related to feed gas composition variability across both facilities. However, these impacts were partially offset by the ongoing acceleration in the commissioning and startup of the Corpus Christi Stage 3 project. Looking forward, we expect to continue deploying solutions to build resiliency against production variability and bolster our operation reliability year over year, as well as bringing the remainder of the Stage 3 trains online safely and ahead of schedule. We have generated approximately $4.9 billion of consolidated adjusted EBITDA and approximately $3.8 billion of distributable cash flow in the first nine months of 2025, supporting our confidence in our guidance ranges for the full year, which I'll address on the next slide.

During the third quarter, we recognized in income 584 TBTU of physical LNG, which included 581 TBTU from our projects and 3 TBTU sourced from third parties. Approximately 93% of our LNG volumes recognized were sold in relation to term SPA or IPM agreements. During the quarter, we also produced and sold approximately 7 TBTU of LNG attributable to the commissioning of Trains 2 and 3 of the Stage 3 project, the net margin of which in adherence to GAAP is not recognized in income nor our EBITDA or DCF, but rather as an offset to our overall CapEx spend on the project. Our strong financial results year to date enabled our team to deploy another approximately $1.8 billion under our comprehensive all of the above capital allocation plan.

We've now deployed approximately $18 billion of our initial target of $20 billion through 2026 as we continue to invest in our accretive brownfield growth, reduce our share count, and enhance our shareholder returns while retaining the financial strength and flexibility to self-fund future accretive growth across our platform. With a solidly investment-grade balance sheet, we are now on track to surpass the $20 billion deployment target comfortably before the end of 2026. We've already made a dent on our $25 billion target through 2030 with over $3 billion now deployed into our capital allocation pillars in just the last two quarters. During the third quarter, we repurchased 4.4 million shares for approximately $1 billion, bringing our shares outstanding to approximately 217 million as of quarter end.

As you can see from the 10-Q cover, our plan has continued to be active and opportunistic early in the fourth quarter amidst continued volatility, bringing our share count down into the 215 million range. Our buyback activity in the third quarter and beyond highlights the power of the plan and its ability to be opportunistic during periods of share price volatility, especially following the incorporation of mid scale 8 and 9 and our increased run rate forecast into the valuation framework that governs our repurchases. Thanks to our liquidity and balance sheet position, contracted cash flow visibility, and our uncompromising discipline to grow if and only if an investment meets our standard, our buyback consistently stands at the ready to demonstrate our conviction in the long-term value of this company, especially through any volatility or dislocations.

We have now deployed approximately $1.7 billion on the buyback this year through Q3, leaving approximately $2.2 billion on our current authorization, meaning we are on track to seek our fourth share repurchase authorization from the Board in the next year. We continue to make methodical yet opportunistic progress towards our initial target of 200 million shares outstanding and allow our shareholders to continue growing their ownership of Sabine and Corpus over time. For the third quarter, we declared a dividend of $0.555 per common share or $2.22 annualized, which is an increase of over 10% from the prior quarter. With this increase, we have grown our quarterly dividend by almost 70% since initiation approximately four years ago at $1.32 annualized.

We remain committed to our guidance of growing our dividend by approximately 10% annually through the end of this decade, targeting a payout ratio of approximately 20% over time, enabling the financial flexibility essential to our long-term capital allocation plan and our disciplined approach to self-funded and accretive growth. Moving to the balance sheet, during the third quarter we repaid approximately $52 million of the outstanding principal of the SBL 2037 notes based on the fixed amortization schedule, representing the first amortization payment on these notes. In July, we repaid $1 billion of senior secured notes due 2026 at SBL with the net proceeds from the issuance of $1 billion of unsecured notes due 2035 at CQP along with cash on hand.

We expect to repay the remaining $500 million of principal on the 2026 notes with cash on hand over the next few quarters, reducing our interest expense while further desubordinating our balance sheet and strengthening our investment-grade ratings. This all positions the CQP complex to efficiently finance the first phase of the SPL expansion project and maintain its robust distribution policy through construction. During the third quarter, we refunded over $300 million of CapEx on Stage 3, bringing total spend to approximately $5.5 billion unlevered. We also deployed approximately $200 million in the third quarter towards the mid-scale trains ADA 9 North Dakota debottlenecking project. We maintained substantial liquidity with approximately $1.4 billion in consolidated cash and billions of dollars of undrawn revolver and term loan liquidity throughout the Cheniere complex.

We are well positioned to fund our disciplined growth objectives while retaining the significant financial flexibility fundamental to our capital allocation framework. Turn now to Slide 13 where I will discuss our 2025 guidance and initial volume forecast for 2026. Today we are reconfirming our 2025 guidance ranges of $6.6 billion to $7 billion of consolidated adjusted EBITDA and $3.25 to $3.35 per common unit of distributions from CQP. We are raising our full-year 2025 DCF guidance range from $4.4 billion to $4.8 billion to $4.8 billion to $5.2 billion. The $400 million increase to our DCF guidance range is primarily attributable to an improved cash tax outlook in 2025 due to the IRS revising rules in September related to the Corporate Alternative Minimum Tax. The rule change entitles us to a refund of previously paid KMT.

This is in addition to the $200 million DCF benefit in 2025 guided to on the August call from the previous implementation of 100% bonus depreciation going forward starting this year. As always, precisely where we land within the full year guidance ranges will be influenced by the timing of certain cargoes around year end, the ramp up of Train 3 and the timing of Train 4 of Stage 3, as well as contributions from optimization activities during the balance of the year. With the lessons learned from the substantial completion of Trains 1 through 3 and progress Jack highlighted in navigating production variables, we are confident we can deliver financial results within our reconfirmed EBITDA and upwardly revised DCF ranges.

Looking ahead to 2026, we have completed the initial production forecast for both Sabine Pass and Corpus Christi and we expect to produce approximately 51 to 53 million tons of LNG in total across our two sites next year, up approximately 5 million tons year over year inclusive of forecast Stage 3 volumes from Trains 4 through 7 and planned maintenance across both sites next year. While we expect the substantial completion of Trains 5 through 7 to occur across 2026, variability in this forecast is driven by the specific commissioning ramp up and substantial completion timing as well as some general allowance for production variability year to year. Planned maintenance downtime to continue to bolster our resiliency long term across our platform in 2026 is of smaller scale compared to the major turnarounds we executed this year, supporting 2026 to be a record production year again for us.

Year end timing can drive some degree of variability in our full year results. Of the 51 to 53 million tons of production, we forecast approximately 50 to 52 million tons of volume after commissioning and in transit timing year to year, supporting 2026 EBITDA after accounting for approximately 47 million tons of long term contracts in place, up from approximately 43 million tons in 2025. We expect to have approximately 3 to 5 million tons of spot volume available for CMI to sell into the market or 150 to 250 TBTU. Our team has been opportunistically selling and are hedging these open volumes and we currently forecast approximately 1.5 to 3.5 million tons, or approximately 75 to 175 TBTU of unsold open capacity in 2026.

We will continue to work this down opportunistically in coming quarters, especially as we have greater clarity on completion and ramp up timing of the remaining Stage 3 trains. Therefore, we currently forecast that a $1 change in market margins would impact EBITDA by approximately $0.1 to $0.2 billion for the full year, highlighting the cash flow visibility of the contracted platform consistent with previous years. We intend to provide 2026 financial guidance on our February call. We are proud of the team's efforts in enabling the achievement of substantial completion of Trains 1 through 3 and advancing Train 4 schedule since our last earnings call.

With the expected substantial completion of Trains 5 through 7 in 2026 and several million tons of additional contracts starting in 2026, our platform will continue to be comfortably over 90% contracted with investment-grade counterparties generating long-term take or pay style cash flows, which provides us significant insulation from volatility in a rapidly evolving global LNG market. Our achievements thus far in 2025 reinforce our conviction in Cheniere Energy as the premier contracted infrastructure platform with decades of cash flow visibility. We will continue to remain disciplined and focused on enhancing the long-term value proposition we offer to both our shareholders and customers alike for the decades to come. That concludes our prepared remarks. Thank you for your time and your interest in Cheniere Energy. Operator, we are ready to open the line for questions.

Thank you. If you would like to ask a question, please signal by pressing *1 on your telephone keypad. If you are using a speakerphone, please make sure that your mute function is turned off to allow your signal to reach our equipment. Please limit yourself to one question and one follow-up question before rejoining the queue. Again, you may press *1 to ask a question. We'll pause for just a moment to allow everyone an opportunity to signal. We'll take our first question from Jeremy Tonet with JPMorgan. Please go ahead.

Thanks. I just wanted to start off, I guess.

Zach here with the buybacks. Quite the pace this past quarter, and granted it's opportunistic in nature, but just wanted to see any thoughts you might be able to share with regards.

To the pace of the trajectory going forward, given what you've been able to accomplish so far.

Sure. Thanks, Jeremy. Yeah, it was our second billion dollar quarter that we've had since we initiated buybacks a few years back, and I think there's three dynamics to it. It's first liquidity, and as you could see in just the cash balances, we started this year with over $3 billion, and the fact that all of our revolvers are open and we still have the Corpus term loan for CapEx of over $3 billion, we had more than enough liquidity. It gets into valuation, and honestly, you look at these valuations, forget about where it is today, even where it was in Q3, we're basically buying back the stock at an EV to EBITDA that's significantly lower than the CapEx EBITDA of every other FID project that's occurred this year. On top of that is just performance.

As you can tell, the buyback is there, alive and ready to support the stock and our conviction of the long-term value of this company and those decades of contracted cash flows. Going forward, expect more of the same. This buyback program of $4 billion was supposed to go through 2027. Basically, we're on target to need to go back to the board and ask for an upsize next year. Expect that, and we'll keep on trucking along, especially if we are valued at levels that we think are clearly below where, just out in more growth, we can value the company and earn a really good return for our shareholders.

Got it, that's helpful, thanks. Anatol, pivoting to the LNG market.

Picking up some of the commentary you put out there with regards to.

Inflection point, was just wondering if you.

More on lower prices, incentivizing demand. You know what type of demand within.

Are those pockets and the pricing range provided on slide 10?

That is a pretty wide range. Any thoughts, I guess, on how things could shape up versus, you know, the...

Active forward curve versus some of the consultants?

Yeah, thanks Jeremy. Look, we've gone through a multi-year period now with one of the largest disruptions to global gas supply and we've added order of magnitude 30 million tons to the LNG market and now we're going to embark on more than half a decade of adding that much volume on an annual basis. 2026 we do think is a transition year, weather dependent, and obviously it depends a lot on how some of those early price signals and demand elasticity play out. The drivers for that gas demand, which we are very constructive on over the medium to longer term, right, we do think that not only does the LNG market get to that 700 million ton level by 2040, but also the gas market overall will have a robust growth period. It'll be choppy.

It'll be things like power generation. In China, you have over 150 gigawatts installed now. You have no issues with regas capacity. That now has, I believe, 32 facilities up and running and will be 250 million tons of import capacity, just what's operating under construction. That generation fleet is grossly underutilized and that could be a very substantial driver in and of itself. As we've already said, the aggregate installed capacity is going to grow to 800 gigawatts in that theater. That is a driver. You'll also see industrial demand, you'll also see residential commercial demand. The pace at which it absorbs this incremental supply will at times not match the supply timing. That's the reason why we expect this volatility. As Jack says, we'll continue to cheat and continue to contract the 95%+ of our capacity and let our investment-grade counterparties manage vast majority of that volatility.

We'll take our next question from Theresa Chen with Barclays.

Good morning. Thank you for taking my questions. With the EU moving forward to ban imports of Russian natural gas by January 1, 2026, do you think we could see upside to your marketing activities next year with 75 to 175 tBtu of unsold volumes as the block leans further into U.S. LNG during the winter ahead?

Yeah, thank you. Theresa, this is Jack. As you know, we have tried to be very constructive and supportive of the EU and their energy needs. We've delivered over 60%. I think it's close to 66% of all of our cargoes over the last three years have gone to Europe. I would expect that there's going to be other opportunities for us in Europe just based on our relationship with our counterparties there. 24 million tons of our contracts are with EU counterparties and our relationship there is very, very strong. Anatol, do you have anything to add?

Yeah, thanks. Theresa, just not to be too precise, but six months for the short term contract, so that's April of next year. Long term as of January of 2027, which is one of the reasons why we think this winter again is a bit of a transition period. As Jack said, we stand at the ready to support our customers. Obviously have destination flexible volumes. As you point out, Russian LNG has supplied about 11 million tons year to date into the EU, so that volume will be most likely impeded. We don't think it disappears, we think it is a little bit less sort of utilization of the Arctic facilities. Ultimately, unfortunately they will likely find a market, as you well know. It is a little bit of the question mark over this coming winter.

Again, it's order magnitude 10, 11 million tons against the backdrop of 30 and 40 million ton growth years.

Got it, thank you. With the previous comments from Anatol about medium to long term demand elasticity.

Views on project commercialization, given onslaught of competing liquefaction project FIDs we've seen so far this year, how is Cheniere thinking about your own incremental capacity expansion from here beyond what has already been sanctioned?

Yeah, Theresa, thank you. You know, we're going to stick with our Cheniere standards. We're going to make sure that if we're going to invest additional capital into growth, that it meets all of our financial hurdles. Those hurdles are very robust. I'll let Zach go through at least the five or 10 of them that he wants to. We make sure that we are fully contracted, that it meets our hurdle rates, and that we're providing our energy to investment-grade counterparties over the long term. Zach, do you have anything to add?

Sure. I'll just say, we're going to stay to our lane and stick to brownfield LNG development and construction and operations and remain as disciplined as possible in a pretty undisciplined environment right now. The plan, as we've said many times, is we're going to permit the heck out of the sites. We're permitting 20+ million tons at both Sabine Pass and Corpus Christi as we speak. That doesn't mean that's the intention of what we'll FID in the near term. What we have line of sight to FID in the near term is first a Sabine Pass first phase expansion. That would be a train and some incremental debottlenecking equipment, and that project alone would need an incremental berth, tank, or pipeline, and that should be as economic as possible.

With that said, we have a good amount of contracts already on the books signed with CMI that could be assigned to either project that basically cover us off for contracting for a first phase project at Sabine Pass. It's ditto for the fourth large scale train at Corpus Christi. That's slightly behind in terms of the permitting schedule as we just FID mid scale 8 and 9. We'll stick to the standard basically unlevered 10% returns and not at these $5 margins that we see on the curve today and into next year, but comfortably under $3. We're going to stick to the 6 to 7 times CapEx to EBITDA at the same type of margin level. We're going to be 90% contracted to really lock that in and then be in a position where we can fund it 50/50 and be credit accretive.

That's how we've done every project to date and have no intention of slowing that down.

We'll move to our next question from John Mackay with Goldman Sachs.

Hey guys, thank you for the time. I wanted to start on some of the comments on the feed gas this quarter. Jack, I appreciate your walkthrough on everything the team's done to kind of fix that. I guess if you can just talk us through what that looks like going forward. Are there investments you guys can make at the plants or investments upstream? Is it something more, just process and it takes some time? Maybe just walk us through that one more time if you don't mind.

Yeah, John, thank you. First off, there's a lot of variability, right? Our biggest variability has always been weather. We first had fog and a lot of fog at Sabine Pass. We built the third berth and we managed fog. It was hot and humid and we've upgraded fans and we've added windshields. The team constantly surprises me and is able to make small capital investments to get through some of these variabilities. Lately, it's been the variability in the feed gas composition, mostly from the Permian. As some of the larger pipes have come across and have tied in Permian gas into Louisiana, for lack of a better word, we've seen an increase in nitrogen and yes, there are things we can do to help minimize the nitrogen. Nitrogen is an inert gas and it takes up space and there are different ways to combat that.

At Sabine, we've seen the increase in nitrogen. We've changed processes to run it in what we call wet mode, which chills it and pushes it through our system a little more forgiving is what I'll say. Secondly, minute quantities of substances in the gas stream when you're focusing billions and billions of cubic feet to one specific area. 5 billion cubic feet a day to Sabine Pass or 3 billion cubic feet over to Corpus Christi. Minute quantities end up being very, very big. We've seen some heavies. Those are C12s or C12 pluses that are starting to freeze in our system before the liquefaction of the LNG. That's where we've started to use different solvents to clean the heat exchangers. We've been defrosting a little bit more, but the team continues to figure out ways around it.

We have a long-term plan that we're going to implement next year to help us be much more resilient to small shifts in composition within the gas stream.

As we gave preliminary, and it's definitely preliminary, production guidance for next year, we baked a lot of that in in terms of there's some planned maintenance incrementally, in particular at Corpus, in the next year. At least once we get through some of that, we could be in a position to potentially do better than, let's say, 1.5 million tons per train. That's not something we're baking in in October a year ahead before we've done much of that work. Some of those things are baked into this initial forecast. Clearly, we'll give financial guidance to the street on the February call and have a better picture of where production is coming out.

That's clear. I appreciate that. Color. Just a quick one for me, Zach, following up on your comments a couple minutes ago. Can you just remind us at this point kind of gating items for a Sabine Pass Train 7 specifically, and understanding there's a few more moving pieces, but loosely speaking, what's your bogey for potential FID timing?

Sure. We're deep in that FERC process and don't expect to receive that permit till later next year. Then and only then would we even be in a position to break ground and officially reach FID. With that said, we could definitely start LNTPs to an extent with Bechtel Energy next year to start locking in certain costs if it all meets the hurdles again. We're still working that through with Bechtel Energy in development and ensuring that we can get to that, let's say, seven times CapEx to EBITDA or better level.

As we get closer to that, we're going to lock in some long lead items, spend some money down there, and you'll see still a tempered CQP distribution out as we retain some of that variable distribution to make sure the balance sheet is good to go for that project as well as to fund some of this CapEx before we even FID.

We'll take our next question from Spiro Dounis with Citi.

Thanks, Operator. Morning, team. Wanted to start, Jack, maybe with some of your opening comments just around the trade outlook and some of the uncertainty there. I would love just to get your updated thoughts around trade relations, maybe how that's impacted your SPA and commercialization efforts. We know the President in Asia this week, so just curious if you're optimistic that maybe we could see some more announcements come through on the LNG side.

Sparrow, thank you. I mean, it is nice to have a President that's so enthusiastic about our product and what our product can do for the world. At times we need to manage that a little bit, but it's good to have somebody that's out there, out in the forefront. I do expect to see more opportunities for us in Asia. Asia, as you know, is where we see a majority of the growth happening this next decade or two. I see some opportunities there, which is why I have a trip to Asia tomorrow. Thank you, Sparrow.

Yeah, you bet. Appreciate the color there, Jack. Second one maybe for you, Zach, on 2026 volumes. At first flush, they did look a little conservative to us, but it sounds like you're baking in some of that.

I also just wanted to get your sense for what you've assumed around the cadence for trains 5 through 7 reaching substantial completion next year. Especially, you seem to have cut that time in half between First LNG and substantial completion. Dare I say it, is there even a chance that we could see train 8 sneak into 2026?

Do not put Train 8 into 2026 out there. We're only, I think, 20-something % complete with none of the construction as of this call. The team's pretty incredible, but I'd rather them do it safely and get it right. We are optimistic on Trains 5 through 7 to come online next year. As we talk about the guidance range, we assumed a Train 5 in the spring, a Train 6 in the summer, and a Train 7 in the fall. We'll be more precise as we get closer to those dates, as we're right now very focused on the fact that Train 4 is getting closer to first LNG, and we'll see if that's end of year this year, substantial completion, or early next. We are optimistic if there's any acceleration on those trains that could help the production forecast as well.

In addition to that, as you'll start to see, even from Train 1 to Train 2 to Train 3, the time between first LNG and substantial completion keeps on shortening. That would also produce more P&L volumes supporting EBITDA next year as we continue to take advantage of the lessons learned train to train to train. More to come with that in February, but we'll leave it in on the seasonal pattern for now for the next four trains to come online.

I'll leave it there. Thank you, gentlemen.

We'll take our next question from Brandon Bingham with Scotiabank.

We'd just love to hear your thoughts. It's become more commonplace over the past couple of years to have market participants.

Impacts or even just the dynamics in contracting from having these non-LNG operators enter the market?

I'll take a stab at it, I guess, Anatol. This market, a decade ago when we started, if you wanted to buy a U.S. Gulf cargo, you could only call one counterparty and that was Cheniere. Now, as this market surpasses 100 million tons on its way to 250 million tons, you have a very, very different landscape. Of course, we've spoken about the kind of lack of discipline. From our perspective, it seems like projects are getting over the FID finish line with a very broad array of counterparties and at times actually no counterparties at all. It will be a very interesting and challenging dynamic as we go through the period of late this decade and first half of next. That's why we are going to be sticking to that 95%+ contracted portfolio into the hands of credible, experienced counterparties as well as our own.

Cheniere Energy (LNG) Q3 2025 Earnings Call Transcript

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