Please stand by. Good day, and welcome to the Chenier Energy 4th Quarter and Full Year 2025 Conference Call. Today's conference is being recorded. At this time, I'd like to turn the conference over to Randy Bottier. Please go ahead.

Thanks, Operator.

Good morning, everyone, and welcome to Chenier's 4th Quarter and Full Year 2025 Earnings Conference Call. The slide presentation and access to the webcast for today's call are available at Chenier.com. 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 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 slide presentation. As part of our discussion of Chenier's results, today's call may also include selected financial information and results for Chenier Energy Partners LP or CQP. We do not intend to cover CQP's results separately from those of Chenier Energy, Inc. The call agenda is shown on slide three. Jack Fusco, Chenier's president and CEO, will begin with operating and financial highlights as well as Chenier's growth outlook. Anatole Fagan, our Chief Commercial Officer, will then provide an update on the LNG market. And Zach Davis, our CFO, will review our financial results, 2026 guidance, and long-term capital allocation plan. After prepared remarks, we will open the call for Q&A. I'll now turn the call over to Jack Fusco, President and CEO.

Thank you, Randy. Good morning, everyone. Thanks for joining us today as we review our results from the fourth quarter in the full year 2025, and we look forward to 2026. Before we dive into the results and outlook, I'd like to take a moment to acknowledge a significant occasion that occurred here at Chenier earlier this week. On Tuesday, we celebrated the 10th anniversary of our first export cargo, a milestone achievement that not only ushered in a new era of prosperity for Chenier, but for the U.S. and global energy markets as well. The significance of that first cargo cannot be overstated. In fact, earlier this week, I participated in the Transatlantic Gas Security Summit in Washington, D.C., with Energy Secretary Chris Wright and Secretary Doug Burgum, as well as leaders and ministers from over a dozen countries where the anniversary of our first cargo was commemorated. Getting to the point of that cargo being exported was a Herculean effort. Chenier charted an unprecedented path in order to realize our vision of enabling the energy abundance and affordability we enjoy here in America to reach international markets. In doing so, we resolved a maraud of project development challenges to bring Sabine Pass to fruition while rewriting the LNG rulebook on long-term contracting by leveraging the vast natural gas resource and in-place energy infrastructure of the United States. Now, 10 years and nearly 5,000 cargos later, we have cemented our position as the industry's gold standard. We lead the U.S. LNG industry thanks first and foremost to the Chenier workforce and their steadfast commitment to safety and excellence, which they demonstrate every single day. We also wouldn't be here today without the unwavering support of our over three dozen long-term customers, construction partner Bechtel, regulatory agencies, financial stakeholders, and our community partners. Together, we have achieved something truly transformative in our first 10 years, and we are just getting started. Please turn to slide 5, where I'll highlight our key results and accomplishments for the fourth quarter. We had an excellent fourth quarter operationally, and we generated consolidated adjusted EBITDA of approximately $2 billion, bringing our total for the full year to $6.94 billion at the high end of our guidance range. We generated distributable cash flow of approximately $1.5 billion in the fourth quarter and approximately $5.3 billion for the full year, which is approximately $100 million above the high end of our guidance range. Net income totaled approximately $2.3 billion in the fourth quarter and over $5.3 billion for the year. 2025 was a record year for LNG production, totaling 670 cargoes or over 46 million tons. During the fourth quarter, we exported 185 LNG cargoes from our facilities. This is an increase of 22 cargoes compared to the third quarter, as not only did we benefit from additional volumes from Stage 3 and the seasonal benefit in production, we also had improved production reliability and reduced unplanned maintenance compared to the third quarter as our efforts to mitigate some of the feed gas-related challenges we addressed on the last call delivered positive results across the quarter. Looking ahead to the remainder of 2026, we are on track to set another annual production record, aided by the expected completion of the remaining three trains at Stage 3. I'm pleased to introduce our 2026 financial guidance of $6.75 to $7.25 billion in consolidated adjusted EBITDA, $4.35 to $4.85 billion in distributable cash flow, and $3.10 to $3.40 in per unit distributions of CQP. These ranges reflect our forecast for higher production in 2026, offset by lower margins on spot cargos than last year, as well as the startup of a number of long-term contracts over the course of the year. We look forward to once again delivering financial results within our guidance ranges. We have great news to share on the capital allocation front. The 2020 vision capital allocation plan we revealed in 2022 has been completed, and in typical Chenier fashion, it was completed ahead of schedule. We have deployed over $20 billion across our capital allocation priorities and have achieved over $20 per share of run rate DCF. In conjunction with With our advanced progress on capital deployment and share buyback, our Board of Directors has increased our share repurchase authorization to over $10 billion through 2030, after approving a $9 billion increase. Zach will have more to share on this major extension of our capital allocation plans shortly. And lastly, early this morning, we announced a new long-term SBA with CPC Corporation of Taiwan for up to 1.2 million tons per annum on a delivered basis. It commences later this year and extends through 2050 and will bolster our contracted profile as we continue to grow our platform. This is our second long-term SPA with CPC following the approximately 25-year 2 million ton SPA we signed in 2018, which commenced in 2021. In light of the recent volatility in the market, this SPA is a salient reminder that our product provides customers with long-term visibility, certainty, and reliable supply through commodity cycles, and contracting appetite isn't dictated by the trajectory of margins in the front of the curve, but to support the lasting demand for our product for decades to come. I am very proud that CBC has become another repeat long-term customer of Schneer. It is clear evidence of how much the market values the reliability and customer focus that has come to define our first 10 years of LNG export operations. Turn now to slide 6, where I'll provide an update on our major growth projects. Construction progress on Corpus Christi Stage 3 has advanced to approximately 95% complete, with the substantial completion of trains 3 and 4 in the fourth quarter. Our forecast for the expected substantial completion of trains 5, 6, and 7 to occur in spring, summer, and fall, respectively, is unchanged from our last call, but moving in the right direction based on recent progress. I am pleased to announce that 1st LNG has been achieved at train 5 this week, supporting that forecasted timeline. On CCL mid-scale trains 8 and 9, groundwork and site prep continues, progressing extremely well, with work streams currently focused on concrete piling and spool and steel fabrication, as well as further materials procurement. Piling work is already halfway complete, and all the piles for train 8 have been set. Substantial completion for these trains is forecast in 2028, so I'm optimistic we have some advancement on that timeline as construction progresses. And nearby at our Gregory Power Plant, work on the planned expansion and interconnect is going well. We are set to optimize our power strategy with a ramp-up of Stage 3 and mid-scale 8 and 9. The SPL expansion project is our next major growth project that we are making significant progress along multiple parallel paths, advancing the first phase of this project towards FID as our visibility and confidence in this project continues to grow. We have secured significant commercial support for this brownfield capacity expansion. We continue to prepare the CQP complex for conservatively financing the project, And we are working diligently on project costs with Bechtel while advancing the project through the permitting process. We currently expect to be in a good position to receive our permits by the end of this year and make FID on the first phase in 2027. Back at Corpus Christi, our major CCL expansion is advancing well, with the critical path items and FID timeline of a brown-filled Phase I approximately six months to a year behind the same at SPL, as the full FERC application was submitted earlier this month. Including the Phase I expansions at Sabine Pass and Corpus Christi, we have line of sight to creatively grow our LNG platform by approximately 50% from today, while adhering to our disciplined and capital investment parameters and meeting the Chenier standard with our most brownfield opportunities in focus. We are full steam ahead on these development projects and have excellent line of sight to bring both of these projects to life and deliver market-leading contracted infrastructure returns to our stakeholders. With that, I'll now hand the call over to Anatoly to discuss the LNG market. Thank you again for your continued support of Chenier.

Thanks, Jack, and good morning, everyone. Before I get into the LNG market update, first some comments about the SPA we announced this morning with our longtime customer, CPC. It's not only a core long-term transaction in its own right, but also an all-but-perfect summation of our strategy and value proposition. Like most of the transactions we have executed in this cycle, it is with a repeat customer. Reliable LNG supply is absolutely critical to Taiwan and its rapidly growing economy, and we take pride that CPC put its trust in our ability to perform. This approximately 1.2 million ton contract is yet another transaction we have executed that extends beyond the middle of this century and features a number of bespoke components as buyers continue to value Chenier's customer-focused, tailored solutions. We look forward to starting this incremental tranche later this year with our usual unwavering commitment to our multi-decade partner, CPC. All of the things that set us apart from the competition, safety, operational excellence, customer-first approach, and a stellar execution track record chief among them, have and will continue to contribute meaningfully to our commercial approach and ability to sign contracts like this one that support our disciplined growth Together with constructive LNG market fundamentals supporting a clear need for more capacity, we'll continue to leverage our advantages in the market to creatively commercialize our brownfield growth projects and target market-leading, multi-decade returns to shareholders. Now please turn to slide 8. As you can see from the chart on the left, 25 was another year of generally elevated and volatile spot prices, as trade disputes and geopolitical conflicts fueled uncertainty and sent prices soaring at various points throughout the year. Overall, however, the general price trended lower over 25, aided by new LNG supply beginning to enter the market. A key driver supporting the overall elevated prices relative to historical norms, remained a strong pull on LNG cargoes from Europe. Europe set a new annual record for LNG imports in 2025, as demand rose approximately 27% year-on-year, reaching about 125 million tons. The key drivers for this growth remained the replacement of Russian gas and the replenishment of underground storage inventories, which were approximately 20 BCM lower year-on-year in the fourth quarter, and remain at a 14-BCM deficit today, or approximately 140 cargos. European storage levels are once again starting the year at five-year lows, about 25% behind last year, in fact, with a cold snap in January spiking prices once again. Until additional volumes come to relieve the market, Europe will likely maintain its premium pricing to ensure readiness for next winter. Furthermore, a 17 BCM year-on-year reduction in pipeline imports from Norway, North Africa, and of course Russia were more than offset by LNG imports, as shown on the top middle chart. We expect these drivers will help keep LNG demand in Europe resilient, especially in light of the EU Parliament's vote to ban all residual Russian gas, including Russian LNG, by 2027. In contrast, Asian LNG imports in aggregate contracted slightly last year, likely as a consequence of the still elevated levels of TTF spot prices in 2025, incentivizing greater deliveries into Europe. Asia's LNG consumption was down about 4% in 2025, lower by 12.4 million tons year-on-year to 270 million tons, but still comfortably within the five-year range for the region. A mix of factors were at play across Asia driving these import levels. Seasonal demand was impacted due to milder weather in the region, while China, the largest and most diverse LNG market in the world, continued to redirect cargos to markets of higher margin, namely Europe, as it took advantage of its LNG delivery flexibility. While many of the major markets in Asia saw year-on-year declines, China's was the largest as LNG imports declined 16%, or 12.1 million tons year-on-year, due to muted industrial demand, macroeconomic challenges, and optimizing some of its LNG into higher-value markets. Gas demand growth of about 3% in China in 2025 was below the 7% average in recent years. Additionally, higher piped gas flows from Russia, which were up 30.6% year-on-year, and increased domestic gas production, up 6.3% year-on-year, also contributed. With that said, as we watched LNG prices fall in November and December and into January, we saw a rapid increase in Chinese LNG imports, highlighting the at-the-ready price-sensitive depth of demand for LNG. These are short-term dynamics, however. We continue to expect robust growth in China's appetite for LNG in the medium to long term to become the LNG industry's first market to surpass, meaningfully surpass, 100 million tons per annum. In contrast, across JKT, LNG imports were up 1.4 percent, or 1.9 million tons in 2025. The year-on-year growth in the market area was supported by the continued phase-out of nuclear power in Taiwan and active restocking in South Korea, both of which were partially offset by lower gas burn in Japan. LNG imports to South and Southeast Asia decreased by 3.8 percent or 2.6 million tons year-on-year, in large part due to milder weather versus 24, as well as these being price-sensitive markets. India's imports were down 7 percent to 25 MTPA, while those in Pakistan were down 15 percent to 6.7 MTPA. High spot prices, coupled with efforts to reduce gas sector circular debt in Pakistan led to levy and tariff increases, which curtailed LNG imports amid macroeconomic challenges following the devastating monsoon floods of last year. In summary, slightly lower LNG imports year on year across Asia are in large part due to sustained elevated price levels in 2025. But we are steadfast in our expectation that moderating pricing going forward will generate a marked increase in gas and LNG consumption, as evidenced by the late-year surge in imports when price is moderated, as well as the continued strength in long-term contracting across the region as counterparties seek to secure and diversify their gas supply into the second half of this century. We expect the price trajectory to continue to normalize as supply additions increase. We saw this starting to materialize at the tail end of 2025 when production from our Corpus Christi Stage 3 trains, among others, began to ramp up in scale and size. Additionally, given the record level of USFIDs taken last year, we see fairly ratable supply growth over the next five years, which we expect to further moderate and stabilize the forward price outlook to bring the depth of LNG demand to the forefront. Let's turn to the next page to expand on this. Commercial activity in 2025 enabled project sponsors to greenlight over 60 million tons per annum of LNG capacity in the U.S. and about 10 MTPA in other regions. These projects are expected to enter service by the end of the decade, which, along with a few additional projects vying for FID this year, should support a steady stream of supply additions extending into the early 2030s, creating the next LNG supply wave. The escalation between feast and famine in relatively short cycles in the industry in recent decades has made it challenging for price-sensitive demand segments to grow and prosper. This has particularly been the case in the emerging markets of Asia, where there has been limited aggregate import growth since 2021 amid the current multi-year period of low supply growth and high spot prices. The region's price elasticity is clearly illustrated by the correlation between the spot price of LNG in the price-sensitive markets in Asia, excluding JKT, and the rate of growth in LNG consumption. During the five-year period to 2021, spot prices in nominal terms averaged approximately $7 in MMBTU, and Asia's price-sensitive markets grew imports by a compounded average rate of almost 20%. In contrast, the compound annual growth rate for these same markets dropped to just 1.7% in the period from 21 to 25 when JKM averaged $18 in M. We expect lower LNG spot prices with the coming growth in supply to stimulate demand in these markets over the coming years. While the scale of impact and specific growth drivers vary by market, the overall net growth in each of the Asian regions is expected to be above the levels seen over the past four years, and in most cases, well above. In summary, 25 marked the end of a multi-year period of low supply growth. We see 26 as the start of a multi-year LNG supply cycle, one that will improve availability and affordability of reliable supply and, in turn, stimulate price-sensitive Asian LNG demand that has historically driven this industry. With two long-term contracts signed with two of the largest Asian LNG buyers in the last six months, we continue to do our part to support the long-term energy priorities and long-term demand growth of the region with our flexible and reliable LNG supply. We believe that safely, reliably, and affordably supporting this growth will allow us to capture incremental long-term commitments in support of our disciplined, accretive brownfield growth strategy. With over 95% of our capacity for the next 10 years contracted, and as you saw in Jack's slide, sufficient contracts in place today to fully underwrite much of our growth up to 75 million tons per annum, we are well positioned to further execute on our capital allocation strategy through the cycles. With that, I'll turn the call over to Zach to review our financial results and guidance.

Thanks, Anatole, and good morning, everyone. I'm pleased to be here today to discuss our financial results and plans going forward. Turn to slide 11. For the fourth quarter and full year 2025, we generated net income of approximately $2.3 billion and $5.3 billion, dollars, consolidated adjusted EBITDA of approximately 2 billion dollars and 6.9 billion dollars, and distributable cash flow of approximately 1.5 billion dollars and 5.3 billion dollars respectively. EBITDA came in at the high end of the guidance range, and DCF ended up above the high end of the range despite being close to fully sold out on our open capacity as of the last call. This outperformance can be attributed to further optimization locked in during the fourth quarter, higher lifting margin due to higher year-end Henry Hub pricing, and certain end-of-year cargos being delivered in 2025 instead of early 2026. Compared to 2024, our 2025 results reflect higher total volumes of LNG produced across our platform, primarily as a result of the substantial completion of trains 1-4 at CCL Stage 3, which resulted in almost doubling our spot capacity year-over-year, from approximately 2 to approximately 4 million tons, that we were able to proactively lock in for 25 at similar levels as the year prior, at over $8 per MMBTU margins on average. The year also benefited from higher Henry Hub pricing and more volume supporting lifting margin, and greater optimization activities upstream and downstream of the sites compared to 2024. These increases were partially offset by higher O&M costs primarily related to the substantial completion of the initial mid-scale trains at Stage 3 and the major maintenance turnaround at SBL during the year. While we have many significant achievements to highlight from 2025, I am particularly proud of the execution of our long-term capital allocation objectives and the early completion of our 2020 Vision Capital Allocation Plan, ahead of schedule this quarter after a strong 2025. Last year, we deployed over $6 billion towards accretive growth, shareholder returns, and balance sheet management. We paid out approximately 60% of our distributable cash flow towards shareholder returns in the form of share repurchases and dividends. During the year, we repurchased over 12.1 million shares for approximately $2.7 billion. and the fourth quarter was the second consecutive quarter of over $1 billion in share buybacks. This brought our shares outstanding down to approximately $212 million as of year-end. As of last week, we are down to approximately 210 million shares outstanding, with less than $1 billion remaining on the $4 billion share repurchase authorization from 2024, once again highlighting the power of the plan to accelerate to be opportunistic and value-accretive during periods of share price dislocation to the fundamental value of our highly contracted cash flow profile. For the fourth quarter, we declared a dividend of 55.5 cents per common share, bringing total dividends declared for 2025 to $2.11, representing over $450 million for common shareholders. We remain committed to growing our dividend by approximately 10% annually through the end of this decade, while maintaining the financial flexibility essential to our long-term capital allocation plan and our disciplined approach to accretive growth with an investment-grade balance sheet. In 2025, we repaid $652 million of long-term indebtedness, fully retiring the SBL 2025 notes, partially redeeming the SBL 2026 notes, and amortizing a portion of the SVL 2037 notes. Earlier this month, we paid down the remaining $200 million of SVL 2026 notes, leaving us with no debt maturities anywhere in the Chenier complex until 2027. Our strategic management of our balance sheet earned us five distinct credit rating upgrades during the year, highlighting our trajectory to a mid-to-high BBB investment-grade corporate structure. In 2025, we equity-funded approximately $2.3 billion of CapEx across our business, including $1.2 billion on Stage 3, and deployed over $800 million towards the Midscale 8 and 9 and de-bottlenecking project during the year. We also began drawing on our CCL term loan during the fourth quarter with a $550 million draw, which, in the context of almost $6 billion and over $1 billion funded to date for Stage 3 and Mid-Scale 8 and 9, respectively, highlights part of how we have strengthened the balance sheet over time. In addition, we continue to deploy capital towards the SBL expansion and CCL expansion projects Jack highlighted as we progress development and permitting, as well as on our Gregory power plant to support incremental power needs at Corpus over time as Stage 3 and Trains 8 and 9 are completed. We maintain substantial liquidity with approximately $1.6 billion in consolidated cash and billions of dollars of undrawn revolver and term loan capacity throughout the Chenier complex. We are ideally positioned to fund our disciplined growth objectives while retaining significant financial flexibility fundamental to our capital allocation framework. Turn now to slide 12, where I will discuss our 2026 financial guidance and outlook for Today, we are introducing our full-year 2026 guidance ranges of $6.75 to $7.25 billion of consolidated adjusted EBITDA and $4.35 to $4.85 billion of distributable cash flow and $3.10 to $3.40 per common unit of distributions from CQP. Compared to 2025 results, these ranges reflect additional production from a full year of operations of trains 1 through 4 of Stage 3, the substantial completion of trains 5 through 7 across this year, higher levels of contractiveness as several new contracts will commence during the year, and lower margins on spot cargos as prices have moderated. We also have a one-time benefit from the confirmation of the Alternative Fuel Tax Credit in the first quarter, contributing over $300 million to EBITDA and DCF in our cost of sales. Our production forecast remains approximately 51 to 53 million tons of LNG across our two sites this year, up approximately 5 million tons year-over-year, inclusive of forecast Stage 3 volumes from trains 5 to 7 and planned maintenance and resiliency efforts across both sites. With approximately 4 million tons of incremental contractiveness in 2026, or approximately 46 to 47 million tons of long-term contracts, approximately 1 million tons of commissioning in transit timing volumes, and over 4 million tons of volumes forward sold by CMI to date, which is up from approximately 1.5 million tons as of the last call, we now forecast less than 1 million tons or less than 50 TBTU of unsold open capacity remaining in 2026. Therefore, we currently forecast that a $1 change in market margins would impact EBITDA by less than $50 million for the full year, underscoring the cash flow visibility of the contracted platform. Despite having little open volumes exposed to the market currently in the forecast, we are introducing these $500 million guidance ranges consistent with our prior practice of initial guidance, as results could still be impacted by a number of factors, including variability in our production forecast, the ramp-up and specific timing of substantial completion of trains 5 through 7 at Stage 3, the timing of certain cargoes around year-end, contributions from optimization activities during the balance of the year, and the impact that Henry Hub volatility can have on lifting margins. As we move through the year and the potential impact of these variables on our financial forecast reduces, we expect to tighten the guidance ranges, also consistent with precedent. The year-over-year decline in the 2026 DCF guidance range is primarily due to the discrete tax benefit that we received in 2025 related to the reversal of the previously paid corporate alternative minimum tax in 2024. However, our 2026 DCF range reflects nominal cash taxes as we expect to benefit again from 100% bonus depreciation related to the remaining Stage 3 trains coming online this year. In addition, greater interest costs will be incurred in DCF and no longer capitalized as the Stage 3 trains reach substantial completion. Our distribution for unit guidance at CQP for 2026 is wider than it had been last year as the wider range provides the flexibility to potentially reinvest some of CQP's distributable cash flow towards limited notices to proceed for the SBL expansion project later this year to strategically lock in long lead time items ahead of an expected FID in 2027. Turn now to slide 13. We are proud to announce the completion of our 2020 Vision Capital Allocation Plan. We introduced the plan in the fall of 2022 with the goal of deploying over $20 billion of available cash across our capital allocation pillars of shareholder returns, accruative growth, and balance sheet management to reach over $20 per share of run rate DCF by the end of 2026. And under that program, we have now surpassed those objectives almost a year ahead of schedule. Under the plan, we repaid approximately $5.5 billion of long-term indebtedness, which has led to 22 distinct credit rating upgrades, bringing our issuer rating at CEI from high yield when we started the plan to solidly investment grade today. We deployed approximately $6.5 billion towards equity funding our growth CapEx. While most of this spend was for Stage 3, the initial trains of which have come online ahead of schedule, we also funded CapEx related to Midscale Trains 8 and 9 project, as well as development and engineering related to the SPL and CCL expansion projects, and CapEx related to our Gregory Power Plan adjacent to Corpus. Most significantly, we redeployed almost $9 billion towards shareholder returns in the form of share buybacks and dividends. Under the plan, we repurchased approximately 40 million shares, or over 15% of our shares outstanding, for over $7 billion. We also increased our quarterly dividend by approximately 68% since our inaugural dividend in 2021, representing approximately $1.5 billion of dividends declared under the plan. Given our accelerated progress under our $4 billion share repurchase authorization, with only $1.2 billion remaining as of year-end, and aided by the fact that our LNG platform is over 95% contracted through 2030, our Board of Directors has approved an upsize of our share repurchase authorization to enable over $10 billion from 2026 through 2030. This $9 billion upsize to our authorization is a major extension of our comprehensive capital allocation strategy and a clear mark of confidence in our business model's contracted cash flow visibility and our capital investment discipline that has been developed to withstand the cyclicality of commodity markets. We now have the financial strength to not only opportunistically deploy approximately $10 billion into share repurchases, or approximately 20% of our market cap, over the next five years, but simultaneously grow our dividend by 10% per annum the rest of this decade and budget for FIDs at the Chenier standard at both sites. Clearly, the all-of-the-above capital allocation strategy for Chenier remains firmly intact. These initial phases of the SBL and CCL expansion projects are expected to bring our total liquefaction capacity up to approximately 75 million tons per year. Developed to maximize brownfield economics and supported by decades of take-or-pay contracted cash flows from creditworthy counterparties, we believe these two projects are among the most attractive energy infrastructure investment opportunities in North America, with a risk-adjusted return profile unmatched in this industry. Accordingly, we are We are resetting our target run rate DCF per share to reach approximately $30 by the end of this decade after the full deployment of the repurchase authorization, approximately 175 million shares outstanding, and the completion of the first phases of our brownfield expansions at both Sabine Pass and Corpus Christi. Even before accounting for the growth, we are now in position to reach $25 of DCF per share by simply following through with our upsized share repurchase authorization. As we have done since our first export cargo 10 years ago, we will continue to leverage our many advantages to create sustainable and growing long-term value for our shareholders while supplying our global customer base with our secure, reliable, and affordable LNG through cycles and for decades to come. That concludes our prepared remarks. Thank you for your time and your interest in Chenier.

Operator, we are ready to open the line for questions.

Thank you. If you would like to ask a question, please signal by pressing star 1 on your telephone keypad. If you are using a speakerphone, please make sure 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. Again, press star 1 to ask a question. And the first question will come from Jeremy Tonnet with J.P. Morgan.

Hi, good morning.

Good morning, Jeremy.

Thanks for all the detail today in the slides. And, Anatole, I wanted to turn to slide 9, if I could. And, you know, really the big uptick you see in 26 through 30 demand across Asia there. and was just wondering if you could talk a little bit more on how this backdrop might be influencing the tone of commercial conversations at this point as you look to lock in more supply agreements.

Sure, Jeremy. Good morning and thank you. Look, we've always been of the view that moderate prices are good for this industry. And as we've said over the last few years, one of the things that we expect to change as this wave of supply moves through the market is that the world will recalibrate its outlook on 2040 and that 700 million ton outlook. But even with the 700 million ton outlook, we do expect that the world will need more supply. And we think that our reliable, stable, very secure product is something that will be, if you will, the baseload of that growth. So obviously, long-term contract economics have been much lower than spot prices over the last few years, and we think that that continues to be appealing. Even in the fourth quarter, the world signed over 17 million tons of long-term contracts, and we're proud to be part of that wave, and we'll continue to find these core opportunities to work with customers that value our reliability and security of supply. So we're very, very constructive on what global LNG demand, primarily driven by Asia, is going to look like over the coming decades.

Got it. That's helpful. Thank you. And then just wondering, we've seen some weather activity here, winter storm firm, and just wondering if that had any impact on Chenier here.

Hi, Jeremy. It's Jack. So I'll start and see if Zach wants to chime in. And first and foremost, I was really pleased with the way our operating teams were able to position ourselves and take care of the facilities to make sure that there was no harm to either our employees or to any of the equipment. They once again have far exceeded my expectations on their emergency preparedness at the facilities. There wasn't anything major one way or the other. We saw prices blow out. We saw force majeures predominantly in the Haynesville on some of the gas producers. We were able to manage around that. We were able to put gas back in the system to help support some of the local areas. And at the end of the day, it was a slight positive for us, but nothing material.

Yeah, that's right, Jeremy. I'd say a slight positive to overall optimization for the first month of the year and baked into the guidance we just gave you for this year, but only for January. And just to be clear on how we think about optimization and guidance, if it's not like officially locked in, it's not in the guidance. And so as things accrue into February and for the rest of the quarter, we'll give a clearer update on the May call. But, yeah, we've got a ways to go to catch up to the amount of optimization EBITDA that was generated in 25 for 26. And that's part of the upside to the current guidance that we just provided.

Got it. That's helpful. We await details on further optimization across the year, benefiting the guide. Thank you. I'll leave it there.

And the next question will come from Spiro Downis with Citi.

Thanks, Operator. First question just on commercial progress, a bit of a two-part question. So as you noted, you've got about 10 million tons per annum signed up now to support that next growth project. But curious, does the next SPA that you sign from here start to underwrite the expansions beyond phase one of Sabina Corpus? And maybe if you could, where would you say market LNG contracted margins are right now, especially in light of some competing projects being rationalized?

Yeah, thanks, Biro. So I would say at this point, the first train of our super brownfield expansions is spoken for, and we have some modest amount of work to do on the second one. So I would say at this point, obviously, it depends on the economics and depends on the volume of the SBAs. But I think some single-digit millions of tons still need to be contracted to get us into the right position for train two of the expansions, namely the large-scale train of corpus that we filed for. In terms of market margins, you're absolutely right. It's a very competitive market. We had over 60 million tons of FIDs in the U.S. last year. A number of those tons are still not contracted. So that is a competition that we see in the market, as well as those a few projects that are still trying to get to the finish line. But as you also know, we we do our utmost to not compete in that commoditized market of the 20 year CP product. And everything that you will see from us going forward is is a relatively bespoke product that that receives the premium that we think we deserve for our reliability.

And Spiro, this is Jack. I would say I know in my conversations, in fact, in my keynote address, having 10 years of export capability here at Chenier, over 5,000 cargos this year will be delivered from Chenier and never missing a foundation customer cargo means a lot to the JIRAs and the CPCs. And the Polans, and you can go on and on. Those people that are building the infrastructure, the gas infrastructure now, are willing to pay us a premium to ensure that they get the LNG that they need.

And Spira, I'll just end on some of the numbers. The deals that Anantol and the team have been able to strike over the last year or so, comfortably within our range, solidifying the run rate guidance, if not better. that we've previously given. And the fact that we are well over 95% contracted now, not just through 2030, but 2035, is why we were able to make the announcements we did today. Like the cash flow visibility is just, is basically unparalleled. And we are already fully contracted for, let's say the first phase of Sabine. So if someone doesn't have that in their model, that $10 billion a buyback better be finished a lot sooner. So we are in a good place right now to execute across all fronts and increase shareholder returns and get this thing to 75 million tons.

All right. Yeah, message received. Second question, Jack, you noted in your prepared remarks that you'd already started to benefit on the nitrogen and inert gas side, even in the fourth quarter. But I know last call you sort of indicated that there was a long-term plan in place to deal with that excess nitrogen. So have you once again kind of beaten that estimate? Would you say you've dealt with that issue? Is there still more to go there?

No, there's still more to go there. So it's a combination of issues there, Sparrow. So the nitrogen is just an inert gas. It just takes up space. So we just have to evacuate it as fast and as much as possible. But what was causing us a hiccup or a speed bump during the third quarters was a variability in feed gas with heavies, C12s to be exact, for those of you that are chemists. And the process engineers and the operating folks put their heads together with some suppliers and really some oil companies, and we figured out different operating modes to work in, and that's starting to pay some dividends. So we've been able to adjust our operating modes. We've been able to buy and inject certain solvents that are really starting to show some big benefits for us.

And I'll credit the whole team here that maybe we were at the lower end of production last year in our range, but still got to the high end of our financial guidance. As we proactively sold the open capacity, stage three progressed really well and came online with four trains. and the optimization came through. But this year, the guidance we give and the production guidance that stayed intact since last call bakes in a healthy amount of planned maintenance for these resiliency efforts. And if that doesn't take as long, that'll have to be an update to both production and financial guidance.

And I would say some of the... Oh, for college. Sparrow, some of the capital that you're seeing that Zach talked about that we're deploying is for the longer term to make sure that the front end of our facilities can handle any variability in any gas coming from anywhere.

Color as always. Thank you, gentlemen.

And the next question will come from Teresa Chin with Barclays.

Morning. Great to see the continued commercial success in your second DPC SKA. Maybe putting a finer point on the economics of the commercialization process at this point, Can you provide any quantitative color on your outlook for liquefaction fees based on your recent success and ongoing commercialization efforts? What would you say is the range at this point? And more broadly, going back to Anatole's comments and, you know, the earlier question about elasticity, what evidence of demand elasticity have you seen already in your commercial discussions for long-term contracts, taking into account these significant incremental liquefaction capacity set to enter the market through the end of the decade and beyond?

Yeah, Therese, I'll start and others will pitch in. But, you know, as Zach and I have said for many quarters now, we're very comfortable with the $2.50 to $3 range. And we are really, really doing things, I would say, comfortably above the midpoint of that range. But as we've sets to you and others at this point, I can't tell you that if we needed to get to 20 million tons of additional contracted volumes, we would be able to maintain that. So to your question and Spiro's question, it isn't the situation where the, quote, market economics, end quote, are at that level. In fact, we would say that they're below that level. It is kind of, as Jack already mentioned and I mentioned, it is the counterparties that value our reliability and our flawless performance and our ability to continue to deliver that day in and day out. We think that that is very valuable. And those counterparties that share that view, we are partnering with and delivering those volumes. As we've also mentioned to you, you know, in terms of price elasticity, you know, even in the rearview mirror, the LNG market has had periods where in the aggregate, it has consumed about 600 million tons. So as you look at where price elastic markets can land, the numbers are comfortably above what we have operating and under construction today, well over 1,200 million tons of regas capacity, and that is growing to 1,400 just with what's under construction. You have markets like Vietnam, which, you know, a silly number, but it grew over 200%, obviously from a very small base, But that is a market that in and of itself will probably be well north of 10 million tons by the time we get into next decade. So you're going to see Asia grow from, we think, from the kind of 270 million ton market where it's been stuck for the last few years because of the high prices to well over 400 million tons. And it will continue to grow once that not only affordable supply, but also the fact that it is radically affordable over years continues to stimulate investment. So, again, very sanguine. And at the end of the day, as long as we keep contracting at those economics and underwriting our discipline expansion plans, we hope the market remains constructive and continues to grow. But as you understand, we are quite immune from those dynamics.

That's very helpful. Thank you. Switching gears a bit, as gas to power demand reaches new highs across the U.S., partly driven by growing data center electricity needs, there are concerns that rising LNG exports could exacerbate domestic affordability pressures. What is your view on this? Do you see these dynamics affecting engineers' ability to permit and or commercialize incremental capacity? And how did the domestic affordability issues reconcile with LNG's importance as a strategic trade and geopolitical lever for the U.S.

So I'm going to start because, and then I'm kind of pushing Anatole back because he's jumping at the microphone right now. But, Teresa, so we, it takes us 18 months to two years to get a permit, and our pipeline plans have to be filed with FERC and made public. And then it's another three to four years for construction. And in all cases, we buy FT, firm transportation. As you know, we have it to all five basins. We process seven days a week, 24 hours a day. And we provide a stability and cash flow to the producers and the midstream companies that they've never existed before in their lifetime. So that has allowed them to grow fairly significantly. So when that first cargo left the shore of Sabine Pass and headed to Brazil in February of 2016, natural gas production in the U.S. was, I think it was 67, 68 BCF a day. Today, it's over 110 BCF a day. and that in part is because they see what's coming and they see the amount of exports. Having been for most of my career on the gas-to-power side, gas-to-power doesn't like buying from transportation. They don't like paying for gas forward because they want to price it into the real-time market And they're not real supportive. They'd rather have interruptible supply at the cheapest price possible. And, you know, that that it helps take some of the product up, but but it's not going to be helpful longer term for production. So I think you're starting to see that whole price paradigm on exports shift in Washington as we continue to explain to the legislators and regulators how the markets really work. And then I'll turn it over to Anatole.

Yeah, to not take up too much time, three quick points. One is we don't think we compete for molecules with those incremental demand centers, right? By definition, they will try to build in places that have trapped resource and can't have the infrastructure to access the markets where we see points of liquidity, and that is, as Jack already mentioned, a quasi-religion for us as we supply our customers, too. Two, we think that the market will be very disappointed, let's say, by the rate at which gas demand into power grows. Even the EIA says that 26 and 27 won't see the same level as 24 saw in terms of gas for power generation. And three, as you know, for our product and for our customers, NYMEX is a pass-through and we don't expect tremendous competition in the Southwest Louisiana pool that is NYMEX for those molecules. So we're very optimistic that the domestic resource is there to meet all needs and we are very careful about how we approach the expansions and our current infrastructure is more than sufficient to avail us of the molecules that we need.

Thank you for that comprehensive answer.

And we'll go to Jean Ann Salisbury with Bank of America.

Hi, good morning. In 2025, I believe there was really significant EPC CapEx escalation in LNG greenfield casts. Can you talk about what you see as the drivers of that and whether that has begun to moderate? And as a follow-up, CapEx escalation is impacting brownfield projects like yours as materially.

Jean-Anne, as you know, we have FID trains eight and nine, and we're able to do it within our financial parameters that Zach has laid out for the company and for all of you in the past. We do see some escalation. We're working through it with our partners, Bechtel. We've been able to manage it by doing some limited notices to proceed on some longer lead time items. I would say at this point, it's the lead time that worries me more than the inflation. And it's just the way that we've been able to manage our projects. We also have went back and basically went back to our ConocoPhillips optimized plan to get economies of scale, to get our dollars per ton down. And we've asked both for the SPL expansion as well as the CCL expansion to just give us exactly the same train you gave us the last time. So for SPL-7, I just want another SPL-6, identical. And for CCL-4, I just want CCL-3, again, identical. And I think that's going to help us on all fronts.

And I'll just add, like, when it comes to the math, the math is pretty transparent as, like, we file quarterly. what our CapEx is and our PP&E is. But basically, we have the lowest cost per ton, the best or the highest SBAs, the lowest leverage, and the least amount of equity partners. So I think we're pretty well-placed for the FIDs of train seven and train four. And what we've said before, we're permitting a lot more than that, but we see a path to hold to the standard by being as super brownfield as possible right now.

Very clear. Thank you.

And moving on to Michael Bloom with Wells Fargo.

Thanks. I guess it's still morning here. In terms of your December FERC filing to increase CCL Stage 3 and mid-scale 8 and 9 by 5 million tons, can you just talk about the timing to achieve that expansion And how do we think about the use case for that incremental capacity at those two facilities?

Yeah, those types of filings are the fact that we continue to de-bottleneck and engineer the site in a way that there might be more opportunity than, say, the 60-plus million tons from the existing assets that we plan to try to take advantage of over time. And that's what that increment would be, is to kind of accommodate peak production at certain times of the year at that site. And it kind of folds into this whole story that we're not just going to FID, likely a train at each site, but we're going to FID a train at each site and some other de-bottlenecking projects. And that's how we get to 75 million tons. So, this is just part of the overall plan that there's going to be ideally a first phase of a train four at Corpus, but some other stuff that's going to make the economics so crystal clear that they're creative and within our parameters.

Okay, got it. That makes sense. Thanks for that. And then, in terms of the new CPC contract you announced this morning, when do you expect it to kick in during 2026? Thanks.

It starts mid-year. And to your previous question, you know, some of the transactions and how we negotiate them kind of going forward, to Zach's answer, includes some of that flexibility that we can take advantage of as we de-bottleneck. So that's why we're a little cagey with the 1.2 million tons. That is the number through the vast majority of the term, but it includes some flexibility starting middle of this year.

Understood. Thank you. And the next question comes from Jason Gableman with TD Callen.

Yeah, hello. Thanks for taking my question. You mentioned the ramp-up and corpus stage three is going very well, and it seems like those trains can kind of come online perhaps earlier than what you have contemplated in your volume guidance. So just wondering how you think about the upside to that volume guidance that you gave.

Still early on in the year, and I think everyone could take comfort in the guidance that we gave did not update substantial completion dates of trains five through seven. But mind you, we just had earlier this month, first LNG at train five of stage three. But to put some math on it, if all three trains were a month early, that's comfortably over $50 million of incremental EBITDA at current margins over the year. So that could be upside, but today in February, too soon to tell, and we'll give updates as these trains come online over the coming year. But things are progressing really well. And, yeah, we're already four for four, and it's looking like a five for five of being early.

Yep. Thanks for that. And my follow-up is just thinking about the additional expansions that you have at Sabine and Corpus beyond these very brownfield trains. And, you know, I think, Anatole, you mentioned that you have kind of 20 million tons worth of SBA opportunities at the higher margin guidance that you kind of embed in your economics. Do those support these higher-cost kind of trains beyond the initial brownfield opportunities? Because it sounds like the trains after the initial ones at the Beanbass and Corpus are probably going to be a bit more expensive.

Yeah, Jason, sorry if I misspoke. It's kind of the other way around. I was saying that if we had to do 20, we would not be able to today maintain the $250 to $3 standard, right? quote, the market for the U.S. product is sub-250 today. It is our performance and our reliability and our commercial engagement that gives us the ability to capture these premium contracts. But we are in an enviable position standing on the shoulders of the teams at Chenier that have continued to deliver this performance over, as Jack said, a decade plus a couple of days that we're able to capture these additional volumes that that should allow us to maintain those brownfield super brownfield economics and meet our investment parameters beyond that it's uh i'll let the guys chime in but it's kind of a step function change in capex for ton that and that market the market economics today we don't see supporting meeting our investment parameters.

Jack's whiteboard got us to 75 million tons and we'll go from there.

Got it. Thanks for the answers.

And our last question will come from John McKay with Goldman Sachs.

Hey guys, thank you for the time. A quick one on just going back to the macro for you, Anatole. I just want to go back to slide nine where you guys are showing this pretty strong growth rate for China through 2030. I was just wondering if you'd underline that a little bit more with what price you think you need to underwrite that growth. And, you know, you have the sub-comment around coal, the kind of gas switching in there, just what your general framework for that in terms of magnitude could be.

Yeah, I'll give you our guess, obviously subject to a lot of hedging, but we think somewhere in the $8 to $9 delivered range. The great thing about the Chinese market is it is massively fragmented and distributed. It is going to be approaching 300 million tons of regas capacity, a TCF of storage. It's going to blow through 200 gigawatts of installed generation capacity, mostly along the coast. So at the right price, it has the capacity to consume a very substantial amount of volume. But as you saw in 25, for a host of reasons, it behaves as the quintessential invisible hand and redirects cargoes to where they are most profitable. Dozens and dozens of companies, multiple business models, obviously competing fuels, et cetera. But we think at that high single digit level number, backdrop of $60, $65 rent, you're going to see China come roaring back like it did in 18-19.

Super interesting. Thank you. Last quick one for me. I think this was for Zach, but maybe Jack as well. I'd just be curious to hear your latest thoughts on the dividend in terms of where that could grow over time, particularly now that you're framing up this $30 per share number and how that maybe plays back and forth with buybacks.

Sure. So everything we even announced today is just following through with what we've said in the past. And one of the things we've said in the past is that we're committed to growing the dividend by basically 10% a year through the decade. And eventually, over time, we'll get to something over 20% of a payout ratio. clearly our shareholder return policy is just different than everyone else in midstream we pay out about 60 percent which is probably above on average the rest but 50 of that 60 percent is buybacks whereas it's basically all dividend for the others this flexibility allows us to not only uh basically self-generate the cash flow to fund the equity for stage three and the first phases at both projects, but this flexibility to be opportunistic like we were the last couple quarters and earlier this year on the buyback. So I think we're going to keep it this way. It really enhances the financial flexibility of the company, but that 10% compounding gets very powerful later on this decade.

That's clear. Thank you. Appreciate the time.

And that does conclude the question and answer session. I now turn the conference back over to you.

I just want to say thank you all for the last 10 years of support. It seems like just yesterday, but it also feels like we're just getting started.

So stay tuned.

Thank you. That does conclude today's conference. We do thank you for your participation and have an excellent day.