Good day, and welcome to Cheniere Energy’s Second Quarter 2023 Earnings Call and Webcast. Today’s conference is being recorded. At this time, I would like to turn the conference over to Mr. Randy Bhatia. Please go ahead, sir. Thanks, operator. Good morning, everyone, and welcome to Cheniere’s Second Quarter 2023 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; Zach Davis, Executive Vice President and CFO; and other members of Cheniere’s senior management. 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 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 and 2023 guidance. After prepared remarks, we will open the call to Q&A. I will now turn the call over to Jack Fusco, Cheniere’s President and CEO.

Thank you, Randy. Good morning, everyone, and thanks for joining us today as we review our second quarter results and improved full-year 2023 outlook. Following a record-breaking year for the LNG industry, activity levels, particularly in the U.S., remain elevated with significant commercial momentum and multiple projects having reached FID this year as energy consumers worldwide look to secure cost competitive, reliable natural gas supply in pursuit of achieving evolving energy, economic, and environmental policies and goals. Such activity confirms liquefied natural gas as a preferred clean energy solution, underscoring its critical long-term role in the global energy mix. Recently, the short-term global gas benchmarks have been volatile as markets try to adjust to a multitude of factors like weather, storage, and economic growth that drive all commodity businesses. With over 150 million tons under construction globally and expected to come online over this decade, we expect pockets of volatility in the future as the market adjusts and absorbs this new supply. Cheniere is built to thrive in this volatility as the highly contracted nature of our cash flow profile ensures visibility in our returns while maintaining some exposure to the upside when markets dislocate, like they did last year. At Cheniere, our focus is centered on the long-term fundamentals for natural gas worldwide, and today, those fundamentals remain as strong as ever, with the global LNG market expected to nearly double by 2040. Hundreds of millions of tons of new LNG capacity will need to be developed to meet this demand, and our platform is ideally set up to enable us to accretively capture our fair share. Please turn to Slide 5, where we will review key operational and financial highlights from the second quarter 2023 and introduce our upwardly revised full-year financial guidance. The second quarter was once again highlighted by excellent performance across the Cheniere platform. First and foremost, our relentless focus on operational excellence continues to set us apart, and the successful completion of our planned maintenance at both Sabine Pass and Corpus Christi during the quarter further reinforces our execution capabilities and our stellar operating reputation that our long-term customers expect and appreciate. Also during the quarter, our commercial momentum on the SPL expansion project accelerated with three new long-term SPA in support of that project. And on project execution, Bechtel continues to progress Corpus Christi Stage-3 well ahead of schedule, increasing my optimism for that project being completed ahead of the guaranteed date. We have generated consolidated adjusted EBITDA of approximately $1.9 billion in the second quarter, distributable cash flow of approximately $1.4 billion, and net income of approximately $1.4 billion. These outstanding financial results are the product of our safe, stable, and reliable operations at our facilities. Those operations resulted in the export of 149 cargoes in the second quarter, down from the record levels we have set in recent quarters due to the planned maintenance that was performed. I will review the major turnaround at Sabine Pass in more detail in a minute. Looking ahead to the balance of 2023, our forecast has improved slightly, and today, we are raising our full-year guidance ranges by $100 million to $8.3 billion to $8.8 billion of consolidated adjusted EBITDA and $5.8 billion to $6.3 billion of DCF. The increase is mainly driven by the release of the remaining few cargoes that have been reserved for origination this year as well as some optimization and sub-chartering activity. Zach will provide more color on the guidance, but we have excellent visibility into the balance of the year, and we are confident in our ability to finish the year within these new ranges. During the second quarter, Zach and his team continued to progress on our comprehensive capital allocation plan. We paid down another $200-plus million of long-term debt. We bought back over two million shares for $337 million, and we paid a quarterly dividend of $0.395. Additionally, we opportunistically refinanced our next debt maturity, enabling further financial flexibility and doing so in a cost-efficient manner. On Stage-3, we continue to equity fund that project, investing approximately $200 million during the quarter and over $2 billion to date. As I mentioned on the last earnings call, certain construction activities on Stage-3 are taking place ahead of plan, and I remain optimistic about schedule outperformance and potentially having more LNG volumes in 2025 and possibly the entire Seven Train project complete by the end of 2026. Stage-3 is over 38% complete, and the construction activities continue to ramp up as we now have nearly 1,000 personnel on site. In fact, during the second quarter, the first structural steel was erected, an important milestone for Stage-3 as construction activities advanced and the project begins to take shape. Anatol and his team were also extremely busy in the second quarter as we signed three new long-term SPAs, which are expected to support the SPL expansion project. The SPAs are with Korea Southern Power and repeat customers Equinor and ENN, and represent a mix of FOB and DES terms. The SPAs aggregate to just under four million tons per annum, each with a certain amount of volume tied to an FID of the First Train of the SPL expansion project. While it is early, the diversity of this growing, creditworthy contract portfolio speaks to not only the strength of the long-term fundamentals of the LNG market but also the value of the LNG marketplaces on Cheniere specifically. Turn now to Slide 6. You might recall last year, we sanctioned Corpus Christi Stage-3 with a diverse portfolio of FOB, DES, and IPM contracts signed with customers from Asia to Europe to North America, featuring utility end-users and portfolio players alike. Our customer portfolio is a result of continuous commercial innovation, in a customer-focused strategy that prioritizes collaboration and tailored energy solutions for our customers. We expect the contract portfolio on the SPL expansion project to reflect similar diversity, and our early progress with KOSPO, Equinor, and ENN, all investment-grade counterparties certainly support that. We are extremely excited about the commercial momentum we have gained on the SPL expansion project in such a short time, and I’m optimistic there is more long-term business to do in support of the project this year. We look forward to continuing to build on the contract portfolio that features the breadth, depth, and scale that sets us apart from the competition. Turn now to Slide 7. I will provide some details around the major maintenance turnaround we completed on Sabine Pass Trains 1 and 2 during the quarter. This was the largest maintenance turnaround we have completed yet at Cheniere, and first and foremost, I’m proud to say the event was completed successfully on schedule and, most importantly, with zero recordable or lost time injuries. The turnaround was successful, not only in terms of the important maintenance work executed under Trains 1 and 2 but also as it provides a foundation and some significant lessons learned as we conduct planning for future large-scale maintenance turnarounds. During the month of June, Trains 1 and 2 at SPL were offline for about 25 days. In approximately a 25-day span, we had an incremental approximate 1,400 personnel on site at Sabine Pass. Those personnel completed approximately 10,000 total tasks across 2,000 work orders, with all of that work requiring over 2,250 permits to be issued. To have an effort like that completed in under four weeks speaks to the enormous amount of planning and preparation ahead of time as well as excellent execution and coordination throughout the event. I would like to recognize all those involved, especially our Cheniere personnel and our long-time equipment partners at Baker Hughes for delivering outstanding results and further reinforcing Cheniere’s reputation for successful execution and demonstrating our safety-first culture from start to finish. The success of this major turnaround provides enormous benefits to Cheniere as well as our customers as we will use our experiences to inform maintenance planning in the future with the goal of remaining a world-class operator in the eyes of the LNG industry, employees, and stakeholders alike. Stable and reliable operations have never been more critical as energy security concerns have become a significant priority around the world, and our dependable operations continue to grow as a distinct competitive advantage. Last month at the LNG 2023 Industry Conference in Vancouver, energy security and reliable LNG operations were primary themes in the hallways and in the presentations on the main stage. I was proud to hear many of our long-term customers acknowledge and thank Cheniere specifically for being such a reliable and responsible LNG supplier. The value of that track record is clearly being demonstrated, evidenced by not only the financial results and guidance we reported this morning but also by the four million tons per annum of contracts we signed this quarter. We will continue to press this and our many other competitive advantages as we commercialize additional capacity on the Sabine Pass expansion project. On that note, I will hand it over to Anatol to further address the LNG market and our commercial strategy. Thank you all again for your continued support of Cheniere.

Thanks, Jack, and good morning, everyone. Throughout the second quarter, international gas benchmarks continued to moderate, briefly returning to single-digit territory as global inventory levels reached historic highs amid mild weather and tepid macroeconomic activity in most of the key demand centers. Although the extreme prices and volatility of 2022 appear to be in the rearview mirror, prices remain above historical norms and the market continues to react to news of any potential disruption. TTF contract settled at $7.75 in MMBtu, the lowest monthly settlement since April of 2021, but it is higher more recently, selling July at $11.30 due to extended maintenance in Norway. Similarly, JKM delivery prices dropped from about $14 per MMBtu for April to settle around $9.60 for July and back up around $11.90 per MMBtu for August, thanks to cooling demand load, LNG outages, and summer maintenance. In the U.S., mild weather and production growth kept Henry Hub prices below $3 during the quarter, incentivizing coal-to-gas switching, which, along with lower renewable generation and coal retirement, significantly increased power sector demand, helping balance the market. Strong summer cooling demand, along with the return of LNG facilities for maintenance, has provided milder support to prices, with the August contracts settling just below $2.50. While concerns about near-term market tightness have moderated amid softer near-term fundamentals and continued uncertainty around the pace of China’s recovery, we still view the market to be structurally tight and delicately balanced over the next few years as very limited new supply is set to enter the market globally, leaving further potential for upside risks going forward. With that in mind, let’s now turn to Slide 9 to address regional dynamics in more detail, starting with Europe. During the second quarter, Europe’s LNG imports continued to grow year-on-year despite ongoing efforts to reduce gas consumption. LNG flows to Europe grew 9% year-on-year, or 2.7 million tons for the second quarter on the back of strong U.S. growth in April and May. June imports were relatively flat, driving TTF prices near pre-crisis levels before picking up again on news of an extended outage at Hammerfest LNG and other gas processing facilities. Reduced gas consumption coupled with elevated gas processing facilities continues to weigh on the European market, with data from the IEA suggesting the total European gas demand fell by more than 30 BCM in the first half of 2023. Total electricity generation has declined considerably, falling 9% in the first half of 2023 relative to historic averages, largely as a result of the Russian and Ukraine war and slower economic growth throughout the region. This decline, coupled with notable gains in renewable power generation, resulted in lower demand for thermal generation further contributing to the decline in total gas consumption. However, we started to see a deceleration of these trends in the second quarter as gas burn economics improve. Once overall energy demand levels are gradually restored in Europe, we expect natural gas to regain its share in the supply stack and maintain its critical role in Europe’s power mix. Furthermore, the coal, lignite, and nuclear base load capacity retirement is currently underway in Germany and other European countries should increase demand for gas capacity to maintain grid reliability and flexibility in the power supply stack amid increasing renewable capacity. Let’s now turn to Slide 10 to discuss Asia. While LNG demand across Asia has remained largely subdued year-to-date, increased imports in China, South, and Southeast Asia during the quarter were offset by further demand decline in Japan, with only 14 million tons of LNG imported by the country in the second quarter, representing an 18% decline year-on-year. In fact, May registered the lowest import levels in Japan in 15 years as consumers were incentivized to conserve energy amid electricity rate hikes. Additionally, nuclear availability impacted gas demand in the power sector. We expect this trend to continue as two additional nuclear reactors in Japan are scheduled to restart in the third quarter. Similarly, we expect to see nuclear pressures on LNG spot buying in Korea too, where LNG imports were flat in Q2 with the start-up of the 1.4-gigawatt Shin Hanul 1 nuclear plant last year and the expected startup of the similarly sized Shin Hanul 2 in the third quarter of this year. In India, imports during the quarter trended slightly higher compared to last year, increasing by about 4% year-on-year. Despite the further decline in JKM, prices remained too elevated during the quarter to elicit a meaningful response from price-sensitive South Asian buyers. Southeast Asian demand showed significant growth during the quarter as imports increased 31% year-on-year. Thailand, the main driver of the region’s demand, grew imports 43% or one million tons in Q2 amid a heat wave that sent temperatures soaring. Southeast Asia is expected to be an important growth market in the future as it expands its import infrastructure. The region added a new market in the second quarter as the Philippines imported its first cargo in April. Just last month, Vietnam started commissioning its first regas terminal to service a new 1.5-gigawatt gas-fired power plant. In China, LNG imports picked up in the second quarter, increasing 20% year-on-year. A warm and dry summer triggered a rebound in spot buying activity as a persistent heat wave and low hydropower generation output increased demand for natural gas. China’s hydropower dropped 28% year-on-year in the first half of 2023, helping boost electricity demand from other sources, including gas. In fact, during the quarter, overall gas demand grew 10% year-on-year despite some macroeconomic headwinds in China. Let’s now turn to Slide 11 for some thoughts on the market for long-term contracting. Despite some of the near-term market dynamics discussed earlier, pointing to potentially softened demand for LNG in front of the curve, which as Jack noted, we are largely insulated from; over the last 12 to 18 months, we have witnessed record levels of long-term contracting, particularly for U.S. volumes, as the long-term trade outlook continues to call for further growth in LNG supply. In aggregate, the level of long-term Henry Hub linked contracts signed in 2022 alone far exceeded the total signed over the six preceding years combined, and the market looks to be on track to potentially repeat this level of contract activity this year. As we previously discussed, we expect demand from China and other fast-growing Asian economies to underpin the next LNG supply wave, representing over 70% of the LNG demand growth through 2040. Asian demand, coupled with Europe’s desire to replace Russian supply, has driven recent commercial activity. Although Asian customers and portfolio players have been the largest and most active buyers of long-term volumes globally over the past 18 months, European counterparties have certainly stepped up, signing contracts representing over 20 MTPA, of which 18 MTPA is tied to U.S. projects or about a quarter of the total U.S. volumes signed since 2022. At Cheniere, we have signed over 15 million tons of long-term contracts in just the last 18 months, 30% of which are expected to underpin our future growth at both Corpus and Sabine Pass. While mid-scale Trains 8 and 9 are fully commercialized, the origination team is hard at work constructing the portfolio for the SPL expansion project. As Jack mentioned, our success to date has been a direct result of our resolute commitment to operational excellence and financial discipline across everything that we do. Our contract portfolio today is comprised of a diverse mix of contract structures with varying terms and tenors, all of which were signed with high-quality, creditworthy, and geographically diverse counterparties who value the flexibility and reliability of our products. In fact, several of our recently signed contracts were signed with repeat customers, ENN and Equinor, most recently, but also EOG, ENGIE, and Petro China last year, signaling the mutual commitment to quality we share with our long-term customers. As we continue to commercialize our growth projects, this commitment will remain steadfast. With that, I will 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 second quarter 2023 results and key financial accomplishments, all of which are products of our team’s dedication to operational excellence, seamless execution, and financial discipline as we continue to serve our customers across the world while creating long-term value for our stakeholders. Turning to Slide 13. For the second quarter, we generated net income of approximately $1.4 billion, consolidated adjusted EBITDA of approximately $1.9 billion, and distributable cash flow of approximately $1.4 billion. Relative to recent quarters, our second quarter results reflect a higher proportion of our LNG being sold under long-term contracts, less volumes being sold into short-term markets, continued moderation of international gas prices, as well as the operating cost and production impact from the major turnaround at SPL during the quarter. Once again, these impacts were partially offset by the proactive locking in of a large portion of our open cargoes for the quarter late last year and earlier this year and margins above what is in the market today. During the second quarter, we recognized in income 561 TBtu of physical LNG, including 547 TBtu from our projects and 14 TBtu sourced from third parties. Approximately 85% of these LNG volumes recognized in income were sold under long-term SPA or IPM agreements with initial terms greater than 10 years. As we have noted in prior earnings calls, our reported net income is impacted by the unrealized, non-cash derivative impacts to our revenue and cost of sales line items, which are primarily related to the mismatch of accounting methodology for the purchase of natural gas and the corresponding sale of LNG under our long-term IPM agreements. The further decline in sustained moderation and volatility of international gas price curves throughout the second quarter has served to benefit the mark-to-market valuation of these agreements, increasing our net income line item for the third quarter in a row. With today’s results, we have earned cumulative net income of approximately $8.4 billion for the trailing 12 months and have now reported positive net income on a quarterly and cumulative trailing four-quarter basis three quarters in a row. Throughout the quarter, we continue to deploy capital pursuant to our comprehensive capital allocation plan, increasing shareholder returns, strengthening our balance sheet, and pursuing accretive growth. In June, we refinanced and replaced our existing secured credit facilities at CQP and SPL with a new $1 billion senior unsecured facility at CQP and a $1 billion senior secured facility at SPL. These transactions extended the original maturities, migrated some capacity from the project to parent, de-secured some of our borrowing capacity, and further enhanced our liquidity with more flexible terms. These new facilities, combined with the CEI and CCH credit facilities and our cash on hand, provide ample consolidated available liquidity, affording us even greater optionality as we continue to execute on our long-term capital allocation plan while effectively operating and constructing the second largest LNG platform in the world. During the quarter, we repaid a little over $200 million of long-term indebtedness through our open market repurchase program, substantially all of which was used to repurchase a portion of the senior secured notes due in 2024 at SPL. In June, we further addressed these notes opportunistically with our inaugural investment-grade offering at the parent level, $1.4 billion of 5.95% senior unsecured notes at CQP. The net proceeds from this offering were used to further refinance and redeem approximately $1.4 billion of the SPL 2024 notes, not only extending our maturity but also de-securing and further de-subordinating our balance sheet, all three of which are key tenets to the balance sheet strategy set forth in our capital allocation plan. As discussed on previous calls, we plan to address the remaining balance of the SPL 2024 notes with cash on hand later this year and into next, after which point we will have addressed all maturities through early 2025. In the meantime, you can expect we will continue to opportunistically de-lever utilizing our open market repurchase program. On the ratings front, just last week, Fitch upgraded CCH to BBB from BBB-, bringing our project level ratings in line at Fitch. In April, Moody’s announced that CEI and CCH were under review, which, if upgraded, would further solidify our corporate structure as investment grade. As noted on the last call, now that we have achieved investment-grade ratings across our corporate structure, going forward, we are targeting a one-to-one ratio of de-leveraging and share buybacks on an aggregate basis. During the quarter, we repurchased approximately 2.3 million shares of common stock for approximately $337 million. As we have previously noted, there will likely be a catch-up trade over the next year or two in order to achieve that one-to-one ratio where our opportunistic repurchase plan will outpace debt repayment over that time. We are confident that we will deploy the remaining $2.8 billion of our share repurchase authorization to complete our $4 billion plan ahead of schedule, as our goal to repurchase approximately 10% of the company remains intact. We also declared our eighth quarterly dividend of $0.395 per common share for the second quarter last week. Later this year, we expect to be able to step up the dividend in line with our previous guidance of growing our dividend by approximately 10% annually into the mid-2020s through construction of Stage-3. And for the final pillar of our comprehensive capital allocation plan, disciplined growth, we funded approximately $200 million of CapEx at our Stage-3 project during the quarter with cash on hand as this remained the most efficient form of funding during the quarter. However, we will have over $3 billion available on our CCH term loan that we plan to utilize in the coming years. As Jack mentioned, the Bechtel and Cheniere teams have made meaningful progress year-to-date, so we are optimistic on the timing of those volumes and our ability to bring another over 10 million tons to market ahead of schedule. Turning now to Slide 14, where I will discuss our 2023 guidance and update you on our open capacity for the remainder of the year. Today, we are raising our full-year 2023 guidance ranges by $100 million to $8.3 billion to $8.8 billion in consolidated adjusted EBITDA and $5.8 billion to $6.3 billion in distributable cash flow. With respect to our EBITDA sensitivity for the remainder of the year, we have an immaterial amount of unsold LNG remaining. So we have excellent visibility of delivering results comfortably in these ranges for the year and in cargoes originally reserved for origination. Combined with the incremental margin from optimization activities, this gives us further clarity around our expected financial results for the year and supports the increase to our ranges today. As always, our results could be impacted by the timing of certain year-end cargoes heading into 2024, as well as incremental margin from further optimization of upstream and downstream of our facilities. Our distributable cash flow for 2023 could also be affected by any changes in the tax code under the IRA. However, the guidance provided today is based on the current IRA tax law guidance in which we would not qualify for the minimum corporate tax of 15% this year. However, as noted previously, both of these dynamics would mainly affect timing and not materially impact our cumulative cash flow generation through the mid-2020s as we think about our overall capital allocation plan and our 2020 Vision goals. Similar to this past year, we look forward to providing additional insight on our 2024 production profile and open capacity on our next call in November, with official 2024 financial guidance to come out with our Q4 and full-year 2023 results in February. As we have consistently forecasted, including in our 2020 vision, 2024 may end up being our most contracted year ever on a percentage basis, ahead of Stage-3 coming online in 2025 and 2026, which is expected to grow our operating LNG portfolio to over 55 million tons per annum. Despite some near-term challenges in the market like cost inflation, higher borrowing costs, and competition, the global market is clearly calling for new LNG supplies given the many advantages of natural gas as a primary energy source. At Cheniere, we are well-positioned and committed to providing energy solutions for our customers, developing and building projects that deliver appropriate risk-adjusted returns for our investors and stakeholders, and operating and maintaining our facilities with our safety-first culture in order to be the LNG provider of choice for decades to come. That concludes our prepared remarks. Thank you for your time and your interest in Cheniere. Operator, we are ready to open the line for questions.

Our first question comes from Jeremy Tonet with JPMorgan.

Just want to start off with the balance sheet, if I could. I think there was $4.5 billion of cash on the balance sheet. So a mountain of cash there and just wondering how you think about deploying that. Clearly, there will be some debt paydown and some funding for expansions. But as far as return to capital, just wondering if you might be able to provide a bit more color there, just $4.5 billion being a sizable number.

Thanks, Jeremy. This is Zach. When considering the $4.5 billion of unrestricted cash, $1.4 billion of that is related to the bond proceeds from the CQP bond we issued in late June, which was refinanced in early July. You need to factor out at least $1.4 billion from that total. The cash actually available at CEI versus CQP is in the mid-2 billion range. Clearly, there is significant liquidity when taking into account our guidance of around $6 billion of DCF, of which we've generated approximately $4 billion to date. Regarding liquidity, we prefer to maintain about $1 billion on the balance sheet at all times, plus or minus. We likely have another $1 billion to allocate towards the Corpus Stage-3 project this year, in addition to a dividend expected to increase in Q3, similar to last year's guidance. Taking all this into consideration, there are still likely a couple of billion dollars available. I want to emphasize that we intend to maintain a one-to-one cumulative ratio between debt repayment and share buybacks over time, and we are on track to achieve this. Over time, billions of dollars will be allocated to our buyback program. We will continue to adhere to our opportunistic strategy, comply with 10b5-1 rules, and eventually reach the target of $20 per share of run-rate cash flow.

Got it. That makes sense. A couple of billion dollars of cash, nice to have discretionary on the balance sheet there. Maybe pivoting a little bit and just see the guidance raised again there. Wondering if you might be able to provide a bit more color as far as the optimization opportunities, be upstream, downstream, or at the facilities. What they are, how big they are, how sticky they are. Does any of this impact, I guess, run rate EBITDA as you think about it?

So I guess the good thing on that is no, it doesn’t affect run rate EBITDA because we really don’t guide to it until it is firm. As we think about run rate EBITDA over time that is just based on the fixed fees, the open capacity at 2.25 and a basic lifting margin. So these are the types of examples that are the incremental optionality that comes with the Cheniere platform from our brownfield growth to opportunities upstream with lifting margin and being such a big customer to most of the pipes upstream of the plant and the biggest consumer of natural gas in the United States to being a relatively big charter with our DES and IPM deals. What happened in the quarter was we firmed up more of the sub-chartering, let’s say, of some of our length on our shipping portfolio. Once that is firm, I see it in the guidance and that helps move the numbers upward. Add to that we released those four origination cargoes. Anatol and the team build another four million tons without needing much in terms of bridging, and we were pretty much obligated to increase guidance by $100 million this quarter.

We will go next to Jean Salisbury with Bernstein.

Can you speak to what sort of cost inflation you are expecting for Corpus Christi eight and nine, assuming that you do it as you progress there?

Jean, I’m not expecting much. We have been very effective with Bechtel on buying materials when we see low points. I think our overall inflationary environment has been around 10% so far from us being working closely and collaboratively with Bechtel on the procurement. So I would expect that to be the same for eight and nine also.

Great. As a follow-up, Cove Point transacted recently at a much lower multiple than in 2019. Can you just kind of - is this a sign that the LNG space is becoming more challenged? How did you view that transaction multiple?

But it is hard to make that comparison, right, from a single train confined. I mean I have spent a lot of time down in that part of the woods. As you all know, I have a house in Annapolis and there is no growth potential to compare Cove Point to Cheniere, which is not even close to being correct. But you want to get through the share.

Sure. I think there are more dynamics to this than just looking at the multiple. I think they sold to an existing operator, an existing owner, and it is probably the easiest way for Dominion to get out of the business. If you account for no growth to customers, polling versus our FOB, BS, IPM, CMI model where you get all the steady cash flows but also, like this quarter, incremental cash flow from all the optionality that comes with the platform. I think it only reaffirms that we are going to get a premium valuation to anything that Cove Point has or something like that. That is how we think about it. And clearly, even at the share price today, we are barely getting valued at that type of multiple. What we are pretty keen on is every turn on that multiple is probably over $25 to the share price. So we will take it. Yes, I just wouldn’t say it is apples-to-apples.

We will go next to Julien Dumoulin Smith with Bank of America.

This is actually Cameron Lochridge on for Julien. I wanted to start just on the expansion efforts, right, with Sabine, specifically asking kind of how you guys are thinking about open capacity for those trains. Would you give any consideration maybe to carrying in a little more open capacity than you have with some of your other projects? And then on a related note, just any update on the regulatory front, just given some of the recent decisions and whatnot by the DOE and elsewhere?

Cameron, this is Jack. I will start off. And the answer on the first one was exposure to the commodity markets. I would say no. We are going to do this the way we have done trains in the past. We are going to use our financial discipline. We are going to commercialize 85% to 90% of the output of the train that we feel comfortable that we can reliably serve and make sure it meets all of our financial criteria that Zach and the team have laid out many times in the past. As you know, I have spent time in the power business, and that was almost a 100% merchant day in and day out. I felt like a farmer; I was always worried about the weather. We have no desire to invest billions of dollars - continue to invest billions of dollars in American infrastructure and pray that commodity markets will come back our way. The second question was on the regulatory structure or recent regulatory developments. I mean I, for one, I’m guardedly optimistic. I think under Chairman Phillips, FERC is trying to act a little bit more in a bipartisan way. They have approved some major natural gas projects and specifically some LNG projects to move forward, and that has been very positive all around that things are actually being reviewed and approved in FERC. Similarly, I would say at the DOE, Secretary Granholm was very clear when she discussed the critical role of U.S. LNG to support our allies in testimony that you recently gave to the House of Representatives. To me, those are really positive developments on the regulatory front for our expansion opportunities.

Got it. And then maybe one for Anatol real quick. You mentioned European appetite for long-term contracts in your prepared remarks, just how strong that has been of late. Any insight you can share on what is perhaps driving that and for how long you maybe see that persisting?

Yes. Thanks, Simon. I do think that European sort of direct end users will continue to be part of the long-term support equation for U.S. projects. My comments were kind of in the context of Europe not being as big a piece of the equation in 2022 as I would have expected, and that has changed slightly, but it is still only a quarter. The vast majority of that volume moving forward will still be addressed by intermediaries who are still half of that volume. So it has improved. I expect that to continue to be a healthy market for long-term commitments, but it will be very much intermediated by portfolio players as well.

Our next question comes from Brian Reynolds with UBS.

We continue to see some exciting announcements around bringing more natural gas from Texas into the LNG Louisiana corridor. So kind of just curious just given the size and scope of the Sabine Pass expansion, if there are any updated thoughts around providing equity support to bring natural gas into Texas and what that permitting timeline could look like just given its crossing state borders and likely need for Greenfield capacity.

Yes. Sure, Brian. As we have said in the past, we view the gas supply component of our projects as an absolutely critical step, and we would not pursue a project that did not have a robust gas supply solution. That said, we view the Permian as a great source, not just for Corpus and this expansion but also for the expansion of Sabine, and we will continue to work with our infrastructure partners to find the best options for supplying the Sabine expansion. Whether that includes equity or not, TBD; obviously, we are not opposed to that, as you saw with our project into the Corpus expansion. All of those options are on the table.

Great. I appreciate all the color. And as my follow-up, Zach, I kind of want to talk about potential funding needs for the Sabine Pass expansion. Just given the attractive leverage and debt levels at CQP with the debt reduction over the past few years and the ability to flex that variable distribution when the time comes to spend capital on expansion. Just kind of curious around if you could provide some more color around funding expectations between debt and perhaps internal equity for the project.

Sure. It will be a debt and internal equity funding for that project over time. We will start thinking about that now - we are thinking about the next few years as we are in development what the leverage metric should be going into FID. Honestly, the lower those leverage metrics are going into FID, the more capacity we would have to leverage up to help funding during construction of the project. Anything that we pay down going forward inside the CQP box is honestly like a pre-investment for that expansion. As we look at our metrics on a consolidated basis, we are right under four times. CQP is a little over four times. It will make sense for some of the debt paydown going forward to be inside that CQP box, and with that, it will give us even more funding flexibility when it comes to FID in a couple of years, where we will live within cash flows, maintain a base distribution, and most importantly, maintain those investment-grade credit metrics so that eventually that, let’s say, high $3 DPU run rate can get to something like $5 or better.

Our next question comes from Sam Burwell with Jefferies.

I know that you have addressed it already, so I don’t want to belabor it too much, but just the buyback seemed a little bit smaller, especially relative to the free cash flow that you put up in the quarter. So just curious if you could maybe elaborate or give a little bit more color on the 10b5 restrictions that are in place, just seeing as you repurchased a lot more stock in Q4 2022 and Q1 2023 relative to what you did in this past quarter despite - I mean, the shares being under pressure in May and June.

Sure. I’m going to go back to the fact that we are thinking about this in the 2020 vision through 2026, and we have a three-year plan for $4 billion. On a cumulative basis, we will get there on a one-to-one debt pay down to share buyback. To focus quarter-by-quarter is honestly not how we are looking at it. If you just look at the time you are referencing where the stock was probably like $20-$25 lower than where it is today, clearly, if there has been pressure for a continued period of time, we probably would have been able to buy more. Abiding by 10b5-1 rules, we are not allowed to affect the share price. We are not allowed to buy at the opening or at the end of the day, and there is a myriad of other rules that we have to be careful of. When there are only three days of extreme pressure at a certain price level, we can’t be a majority of it. I wouldn’t keep score quarter-to-quarter. If you want to think about it, this is the first quarter that share buybacks were higher than debt paydown. If you think about the $4 billion program for three years, we have gone through 30% of it in about 25% of the time. So we are on pace to do that ahead of schedule. That is the plan. What is most important is we are going to get to that $20 per share run rate cash flow ahead of time and buy back 10% of the market cap over time, so it will play itself out. We are not dollar-cost averaging here with our free cash flow, so it wasn’t ever going to be in such a way as you referenced.

Okay. Now certainly, all fair points. Maybe just to follow up on Jack’s comments about the confidence on CCL3 volumes possibly coming on a little bit earlier than expected. I mean what supports that confidence? I mean I understand that the project is 38% complete and the construction is 5% complete. How do you see that progressing? And again, like what drives the claim that volumes can come on early?

I get a weekly construction report, and I was out at the site myself. There are over 1,000 people there. There are over 10,000 pilings installed. Train 1, it is concrete is over 50% complete. The steel is being erected on the site. As I see that progress is way ahead of schedule. I know that we have some very critical components for Train 1 that have been shipped. They just haven’t been received. So I think on the next call, you guys will get a much more fulfilling update on the schedule, but that is what gives me my optimism.

Our next question comes from Ben Nolan with Stifel.

I guess I will put both of these into one. There have been some issues with congestion and water levels and that sort of thing around the Panama. Now I’m curious if that is impacting how you guys are managing your book? And then also, there is a lot of speculation there is likely to be a pretty high increase in - or upward movement in freight costs into the back half of the year. Curious where your freight book looks like at the moment.

Yes. Thanks, Ben. So you are absolutely right. The Canal has had an issue with drought. Clearly, it is something that we are very close to; the canal is a very good partner, and it continues to be a good partner and will be for decades to come. Equally, obviously, Europe has been the market of choice. So that does not affect us nearly as much as it would have. We also have the capacity to address that by going around instead of through the canal, which obviously takes longer but equally obviously saves you the transit fees on the canal. All of that is included in our guidance and in our economics, and we do look forward to continuing to work with the canal and finding good solutions there. In terms of costs, you are referring to sort of charter rates as they continue to be elevated in the back half of the year, driven primarily by the contango into Europe. Of course, as you know, we have our requirements fully covered, and our shipping position reflects that.

Our next question comes from Craig with Tuohy Brothers.

I understand Trains eight and nine for Corpus are significantly hedged on some costs. But we are hearing more and more about EPC price inflation post Port Arthur and Rio Grande FIDs. I wonder if you could opine on the broader market trends in terms of - we used to be looking at six times EBITDA in projects, now maybe somewhere in the seven times might be more reasonable, but some peers might be pressured even at eight times. In terms of peer FIDs, the pressure on the market and how you would think about economics and hurdle rates for SPL Stage 5; can you kind of give us your thoughts?

Sure. Yes, we have heard about all of the other projects mind you; they are Greenfield, et cetera. But as we think about it, if we could sign up the contracts like Anatol and the team have been doing and can do it around, let’s say, seven times CapEx or better, and then you fund it around 50% leverage. We are talking about sub-four times easy on the credit metrics, and you likely can still get to 10% or better on unlevered returns. We are going to do that all day. We are still going to wholly own these projects. We just have a different dynamic economically with an investment-grade balance sheet, cash flowing in the billions, and having already spent $40 billion that structurally and financially, it is just no comparison. So yes, I guess, kudos to some of these folks for getting their projects to the starting line. We have a really nice hand to play here at both sides.

As we go into the next decade, do you see this basically as a systemic competitive advantage that the field is just going to be windowed?

We honestly don’t - we have to focus on what we do here, and Jack reiterates that all the time to us as we execute on these projects. If the economics don’t align, we will be patient, we will be disciplined, and we will just keep on buying back the stock and letting all the shareholders that already believe in Cheniere own more and more of Sabine and Corpus in the meantime. When they do align and it is clearly accretive, we are going to go for it. That is it. If some other folks get projects done, so be it. This industry is probably going to double in the next 20 years or so. Cheniere is not going to build all of it, because we are not doing this for market share.

Our next question comes from Robert Mosca with Mizuho Securities.

Just wondering if you could talk about some of the debottlenecking activity you have undertaken at your non-train portfolio and when or whether you think you could start to push towards maybe the higher end of that 4.9 to 5.1 MTPA per train run rate?

Yes, this is Jack. Yes, I will tell you, Robert, I have been more and more impressed with what my operating folks have been able to do. I am optimistic that they will continue to deliver on it. I think our guidance is right around five. My expectation over time is that it is going to be a little higher than that. When we guide to the five million tons that included and includes our major maintenance that we just talked about. We had significant major maintenance in this quarter and we are still able to hit the five million tons. We are not ready to guide above it just yet, but stay tuned.

Great. I appreciate it, Jack. And for my follow-up question. I know in the past, it really has been part of the playbook to take on equity partners for projects. But any revised thoughts on your appetite if there is a high-quality partner that could also sign up for a chunk of uptake since it seems like those opportunities may still be in the marketplace?

Well, as you know, we have some great equity partners with Blackstone and Brookfield, and I have had a long relationship with them, and they have been very, very good partners for us at SPL. As Zach mentioned, his intent is to fund it with internal equity and internal capital down at CQP, as well as some debt for our expansions. We don’t see a need to complicate our lives with more equity partners than we currently have today.

Our next question comes from Jason Gabelman with TD Cowen.

I want to ask too about the near-term outlook. There are a lot of concerns around European gas storage filling and potential pressure on MVP pricing. I understand that it will have a limited impact on your earnings in 2023, given the way you have locked in pricing. But as you look to 2024, does the prospect of more volatile gas dynamics impact the way you think about hedging your volume exposure next year, either doing some earlier or potentially waiting to get through the fall volatility?

This is Zach. I’m going to start, and then Anatol can give a viewpoint on the market. Basically, I pretty much look at our EBITDA forecast daily, our cash flow forecast daily, and the volatility of the commodity curve definitely moves quite a bit, but the volatility in our EBITDA just doesn’t period. Next year, as I mentioned in the prepared remarks, might be our most derisked and most contracted year we will ever have. We will have less than 100 TBtu open; we will be like almost 98% contracted with all of the contracts starting up, and that will be the case until we have some of that acceleration of Stage-3 ramping up.

Yes, and just to follow-up. What is critical for us and things that we look at, Europe this year will add order of magnitude 60 million tons of import capacity, which obviously comes with storage capacity as well. Asia is on track to match that and in the coming years, exceed that. Europe will add 100 million tons overall probably through this build. Our customers will enjoy, and as Zach said, this year and next year and really into the mid-30s, we are overwhelmingly contracted, and they will enjoy very stable pricing, and we will enjoy the ability to bring volumes into various markets as those markets send the right price signals. The best case scenario is we continue to perform. Our operational excellence continues to deliver these volumes. Our customers enjoy those stable economics, and the world has the capacity to consume these additional volumes. Could you see more volatility? Sure. But we doubt that you will see a repeat of 2022 anytime soon, and the world will put tools in place to address that.

Great. And just a quick follow-up on the other revenue bucket that you disclosed in your earnings. I think a lot of that has to do with chartering out vessels. Correct me if I’m wrong. But given the outlook that fleet rates are going to continue to move higher, should we expect the other revenues bucket to continue to grow?

I will say we don’t forecast anything that is not firm. I look at Corey and the team, and we do expect them to take full advantage of the system and the assets that we have every day looking forward. On top of that, though, we are pretty firm for the rest of this year. I mean we have less than 10 TBTU even open, and some of the upside in the guidance today was things that not only sub-chartering year-to-date but some that they locked in for the rest of the year. There could be some, but it is getting smaller and smaller as we get further along in the year.

Our final question comes from Chris Tsung with Webber Research.

I wanted to just ask if you have noticed any impact from the DOE policy that has reduced the number of viable U.S. LNG projects? And would you anticipate that affecting the cadence of your filing process?

No. All of our projects that are submitted in our filings are either fully commercialized or are progressing well towards commercialization. Therefore, there is no concern regarding the need for significant extensions like we experienced during COVID.

Okay. And just as a follow-up, we are seeing green shoots in the long-term pricing market with prices inching up above like 250 or so. We also noticed Nex amended its pricing across several of its SPAs ahead of their FID. Is that something you are seeing as well as you term out your merchant book and commercialize SPLC chart?

Yes, you are probably seeing that folks with the previous questions around inflation; they can’t seem to make their numbers without having some price escalation. That is probably what you are seeing around the market. It is not easy to get a Greenfield project off the ground. Thank you, everybody. Thanks for your support of Cheniere, and we will talk soon.

Thank you. Ladies and gentlemen, that will conclude today’s conference. We thank you for your participation. You may disconnect at this time.