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California State Teachers Retirement System lifted its position in Cheniere Energy, Inc. (NYSE:LNG – Free Report) by 26,965.4% in the 2nd quarter, according to the company in its most recent 13F filing with the SEC. The institutional investor owned 102,611,534 shares of the energy company’s stock after buying an additional 102,232,409 shares during the quarter. California State Teachers Retirement System owned about 49.68% of Cheniere Energy worth $24,525,183,000 as of its most recent filing with the SEC.

Other hedge funds have also recently added to or reduced their stakes in the company. Strive Financial Group LLC bought a new stake in Cheniere Energy in the fourth quarter worth approximately $25,000. Financial Life Planners bought a new position in shares of Cheniere Energy during the 1st quarter valued at $26,000. Caitong International Asset Management Co. Ltd bought a new position in shares of Cheniere Energy during the 3rd quarter valued at $27,000. Community Financial Services Group LLC acquired a new stake in shares of Cheniere Energy in the 2nd quarter valued at $29,000. Finally, Transamerica Financial Advisors LLC lifted its stake in shares of Cheniere Energy by 91.3% in the 2nd quarter. Transamerica Financial Advisors LLC now owns 132 shares of the energy company’s stock valued at $32,000 after purchasing an additional 63 shares during the last quarter. Institutional investors and hedge funds own 87.26% of the company’s stock.

Cheniere Energy Stock Performance Shares of LNG opened at $292.02 on Tuesday. The company has a market capitalization of $60.31 billion and a PE ratio of 21.74. Cheniere Energy, Inc. has a one year low of $186.20 and a one year high of $300.89. The company has a debt-to-equity ratio of 1.97, a current ratio of 0.87 and a quick ratio of 0.72. The company’s fifty day moving average price is $267.02 and its 200 day moving average price is $256.57.

Cheniere Energy (NYSE:LNG – Get Free Report) last released its quarterly earnings results on Thursday, August 6th. The energy company reported $3.02 earnings per share (EPS) for the quarter, missing analysts’ consensus estimates of $3.11 by ($0.09). The firm had revenue of $5.73 billion for the quarter, compared to the consensus estimate of $4.92 billion. Cheniere Energy had a net margin of 13.57% and a return on equity of 29.80%. The firm’s revenue was up 23.5% on a year-over-year basis. During the same quarter last year, the company earned $7.30 earnings per share. As a group, analysts expect that Cheniere Energy, Inc. will post 16.36 earnings per share for the current year. Cheniere Energy Announces Dividend The firm also recently announced a quarterly dividend, which was paid on Tuesday, August 18th. Investors of record on Monday, August 10th were paid a dividend of $0.555 per share. The ex-dividend date was Monday, August 10th. This represents a $2.22 annualized dividend and a yield of 0.8%. Cheniere Energy’s dividend payout ratio is presently 16.53%.

Wall Street Analysts Forecast Growth Several equities analysts have commented on the stock. Benchmark reissued an “outperform” rating on shares of Cheniere Energy in a research report on Tuesday, May 26th. Argus set a $330.00 price target on Cheniere Energy in a research report on Tuesday, August 18th. Scotiabank reiterated an “outperform” rating on shares of Cheniere Energy in a research note on Wednesday, May 13th. Sanford C. Bernstein assumed coverage on Cheniere Energy in a report on Tuesday, June 16th. They set a “market perform” rating and a $283.00 price objective on the stock. Finally, Weiss Ratings raised Cheniere Energy from a “hold (c)” rating to a “hold (c+)” rating in a research note on Friday, August 21st. Two investment analysts have rated the stock with a Strong Buy rating, fifteen have issued a Buy rating and three have given a Hold rating to the company. Based on data from MarketBeat.com, the stock currently has a consensus rating of “Moderate Buy” and an average target price of $304.35.

Get Our Latest Stock Report on Cheniere Energy

Cheniere Energy Company Profile (Free Report)

Cheniere Energy, Inc is a U.S.-based energy company that develops, owns and operates liquefied natural gas (LNG) infrastructure and markets LNG to global customers. The company’s core activities include natural gas liquefaction, long‑term and short‑term LNG sales and marketing, and the associated midstream services required to move gas from production basins to international markets. Cheniere focuses on converting domestic natural gas into LNG for export, providing a bridge between North American supply and overseas demand.

Cheniere’s principal operating assets are large-scale LNG export terminals located on the U.S.

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ATHENS, Greece, Sept. 08, 2026 (GLOBE NEWSWIRE) -- Dynagas LNG Partners LP (NYSE: DLNG) (the “Partnership”), an owner of liquefied natural gas (“LNG”) carriers, today announced its results for the three and six months ended June 30, 2026.

Half year Highlights:

Net Income and Earnings per common unit (basic and diluted) of $33.4 million and $0.82, respectively;Adjusted Net Income(1) of $28.2 million and Adjusted Earnings per common unit(1) (basic and diluted) of $0.68;Adjusted EBITDA(1) of $51.9 million; and95.7% fleet utilization(2). Quarter Highlights:

Net Income and Earnings per common unit (basic and diluted) of $16.0 million and $0.39, respectively;Adjusted Net Income(1) of $15.8 million and Adjusted Earnings per common unit(1) (basic and diluted) of $0.39;Adjusted EBITDA(1) of $27.6 million;96.2% fleet utilization(2);The Clean Energy was delivered under its new time charter party agreement with Rio Grande LNG, LLC (“Rio Grande”) in April 2026;Declared and paid a cash distribution of $0.5625 per unit on the Partnership’s Series A Preferred Units (NYSE: DLNG PR A) for the period from February 12, 2026 to May 11, 2026; andDeclared a quarterly cash distribution of $0.050 per common unit for the quarter ended March 31, 2026, which was paid on May 22, 2026, to all common unitholders of record as of May 18, 2026.
(1) Adjusted Net Income, Adjusted Earnings per common unit and Adjusted EBITDA are not recognized measures under U.S. GAAP. Please refer to Appendix B of this press release for the definitions and reconciliation of these measures to the most directly comparable financial measures calculated and presented in accordance with U.S. GAAP and other related information.
(2) Please refer to Appendix B for additional information on how the Partnership calculates fleet utilization.

Recent Events: 

Declared a quarterly cash distribution of $0.5625 per unit on the Partnership’s Series A Preferred Units for the period from May 12, 2026 to August 11, 2026, which was paid on August 12, 2026 to all Series A Preferred unitholders of record as of August 5, 2026; andDeclared a quarterly cash distribution of $0.050 per common unit for the quarter ended June 30, 2026, which was paid on August 28, 2026 to all common unitholders of record as of August 24, 2026. CEO Commentary:

“The Partnership delivered a solid second quarter, reporting Net Income of $16.0 million, Adjusted Net Income of $15.8 million and Adjusted EBITDA of $27.6 million, on fleet utilization of 96.2%. Our results reflect the commencement in April of the Clean Energy's new time charter with Rio Grande at an improved rate, and a lower cost of debt following continued deleveraging, with net interest and finance costs down 26.9% year on year.

The Partnership's contract coverage continues to deliver predictable cash generation. As of the date of this release, our estimated contracted revenue backlog stands at $0.73 billion with an average remaining contract term of 4.4 years, and we have contracted time charter coverage of 100%, 100% and 65% of estimated Available Days for 2026, 2027 and 2028, respectively. That backlog, together with our existing cash, gives us the financial flexibility to continue amortizing our debt while returning capital to our common and preferred unitholders.

On the regulatory front, the E.U.'s 21st sanctions package, adopted on July 23, 2026, provides an exemption of the Russian LNG ban to transfers destined for third countries under legacy long-term contracts concluded before February 24, 2022. We believe the transportation of LNG under our two charters with Yamal Trade Pte. Ltd. to destinations outside the E.U. falls within this exemption and, accordingly, outside the scope of the EU LNG ban.

For a fuller description of both the E.U. and U.K. measures and their potential impact on us, please refer to the section of this press release entitled 'Russian Sanctions Developments'.”

Financial Results Overview:

 Three Months EndedSix Months Ended(U.S. dollars in thousands, except per unit data) June 30, 2026
(unaudited) June 30, 2025
(unaudited) June 30, 2026
(unaudited) June 30, 2025
(unaudited)Voyage revenues$41,188$38,613$81,126$77,720Net Income$15,957$13,709$33,383$27,279Adjusted Net Income (1)$15,811$14,463$28,190$28,779Operating income$19,819$19,176$36,329$37,721Adjusted EBITDA (1)$27,642$27,687$51,901$54,775Earnings per common unit$0.39$0.23$0.82$0.52Adjusted Earnings per common unit (1)$0.39$0.25$0.68$0.56 (1) Adjusted Net Income, Adjusted EBITDA and Adjusted Earnings per common unit are not recognized measures under U.S. GAAP. Please refer to Appendix B of this press release for the definitions and reconciliation of these measures to the most directly comparable financial measures calculated and presented in accordance with U.S. GAAP and other related information.

Three Months Ended June 30, 2026 and 2025 Financial Results

Net Income for the three months ended June 30, 2026 was $16.0 million as compared to $13.7 million for the corresponding period in 2025, which represents an increase of $2.3 million, or 16.8%. The increase in Net Income for the three months ended June 30, 2026 compared to the corresponding quarter of 2025 was mainly attributable to: (a) the increase in Voyage revenues, (b) the decrease in Net Interest and finance costs, and (c) the Other operating revenues from related party which relate to the monetization of FuelEU compliance surplus realized in April 2026 pursuant to the transfer of the FuelEU compliance surplus generated by the Arctic Aurora through a pooling agreement (the "Pooling Agreement"). The Pooling Agreement was entered into by the Partnership and other vessel-owning companies who share common ultimate beneficial ownership with the Partnership’s sponsor, Dynagas Holding Ltd. The above increase was partially offset by the increase in Voyage expenses and Vessel operating expenses.

Adjusted Net Income (a non-GAAP financial measure) for the three months ended June 30, 2026 was $15.8 million, compared to $14.5 million for the corresponding period in 2025, which represents a net increase of $1.3 million, or 9%. This increase was mainly attributable to (a) the increase in cash revenues as explained below and (b) the increase in Other operating revenues as explained above, which was partially offset by (i) the lower time charter rate earned by the Arctic Aurora compared to the corresponding period in 2025 and (ii) the decrease in Net Interest and finance costs. The above increase in adjusted net income was partially counterbalanced by the increase in both Voyage expenses and Vessel operating expenses.

Voyage revenues for the three months ended June 30, 2026 were $41.2 million, compared to $38.6 million for the corresponding period in 2025, which represents a net increase of $2.6 million, or 6.7%. This increase was mainly attributable to: (a) the higher time charter rate earned by the Clean Energy under its new charter party with Rio Grande that commenced on April 30, 2026 and was partially offset by a period of 20.5 days off-hire incurred which underwent unscheduled maintenance between the vessel’s re-delivery by SEFE and its delivery to Rio Grande, (b) the increase in variable hire revenues earned under the OPEX pass-through time charters following an increase in Vessel operating expenses as explained below, and (c) the increase of the value of the EU ETS emissions allowances (“EUAs”) due to the Partnership by the charterers of its vessels as a result of the increase in the EU requirement for surrendering allowances for 100% of their verified emissions in 2026 against 70% in 2025, increased market prices and increased voyages to EU ports (the corresponding value of the abovementioned EUAs, which the Partnership is obliged to surrender to the EU authorities, is included within Voyage expenses, therefore the net effect of the EUAs to the Operating Income and Net Income is zero).

The Partnership reported average daily hire gross of commissions(3) of approximately $71,810 per day per vessel for the three-month period ended June 30, 2026, compared to approximately $70,730 per day per vessel for the corresponding period in 2025. The Partnership’s vessels operated at 96.2% and 99.4% fleet utilization during the three-month periods ended June 30, 2026 and 2025, respectively.

Vessel operating expenses were $8.9 million, which corresponds to a daily rate per vessel of $16,322 for the three-month period ended June 30, 2026, compared to $7.7 million, or a daily rate per vessel of $14,189, in the corresponding period in 2025. This increase was mainly attributable to increased crew expenses and increased scheduled engine maintenance costs. As mentioned above, a substantial part of the increase in Vessel operating expenses is counter-balanced by the corresponding increase in variable hire revenues earned on the Partnership’s vessels operating under OPEX pass-through time charters.

Adjusted EBITDA (a non-GAAP financial measure) for the three months ended June 30, 2026 was $27.6 million, compared to $27.7 million for the corresponding period in 2025. The decrease of $0.1 million, or 0.4%, was mainly attributable to the above-mentioned increase in Voyage expenses and Vessel operating expenses, which was partially offset by the increase in cash voyage revenues.

Net Interest and finance costs were $3.8 million in the three months ended June 30, 2026, compared to $5.2 million in the corresponding period in 2025, which represents a decrease of $1.4 million, or 26.9%, due to the reduction in interest-bearing debt and the decrease in market interest rates resulting in a weighted average interest rate from 6.49% in the three months ended June 30, 2025 to 5.90% in the three months ended June 30, 2026.

For the three months ended June 30, 2026, the Partnership reported both basic and diluted Earnings per common unit and Adjusted Earnings per common unit (a non-GAAP financial measure), of $0.39, after taking into account the distributions relating to the Series A Preferred Units on the Partnership’s Net Income/Adjusted Net Income. Earnings per common unit and Adjusted Earnings per common unit, basic and diluted, were calculated on the basis of a weighted average number of 36,382,011 common units outstanding during the period and in the case of Adjusted Earnings per common unit, after reflecting the impact of certain adjustments presented in Appendix B of this press release.

Adjusted Net Income, Adjusted EBITDA, and Adjusted Earnings per common unit are not recognized measures under U.S. GAAP. Please refer to Appendix B of this press release for the definitions and reconciliation of these measures to the most directly comparable financial measures calculated and presented in accordance with U.S. GAAP.

Amounts relating to variations in period-on-period comparisons shown in this section are derived from the condensed financial statements presented in Annex A hereto.

(3) Average daily hire gross of commissions is a non-GAAP financial measure and represents voyage revenue excluding the non-cash time charter deferred revenue amortization, as well as the revenues attributable to the value of the EUAs to be provided to the Partnership pursuant to the terms of its agreements with the charterers, divided by the Available Days in the Partnership’s fleet as described in Appendix B.

Liquidity/ Financing/ Cash Flow Coverage

During the three months ended June 30, 2026, the Partnership generated net cash from operating activities of $21.0 million, compared to $24.3 million in the corresponding period in 2025, which represents a decrease of $3.3 million, or 13.6%, mainly as a result of working capital changes.  

As of June 30, 2026, the Partnership reported total cash of $59.5 million. The Partnership’s outstanding financial liabilities as of June 30, 2026, under the Sale and Leaseback Agreements between the vessel owning companies of the Clean Energy, the OB River, the Amur River and the Arctic Aurora and China Development Bank Financial Leasing Co. Ltd. amounted to $36.5 million, $48.4 million, $49.7 million and $122.0 million, respectively, gross of unamortized deferred loan fees. The financial liabilities under the Sale and Leaseback Agreements are repayable within approximately three years for the Clean Energy, the OB River and the Amur River and within eight years for the Arctic Aurora.

Vessel Employment

As of September 8, 2026, the Partnership had estimated contracted time charter coverage(4) for 100%, 100% and 65% of its fleet estimated Available Days (as defined in Appendix B) for each of 2026, 2027 and 2028, respectively.

As of the same date, the Partnership’s estimated contracted revenue backlog (5) (6) was $0.73 billion, with an average remaining contract term of 4.4 years.        

(4) Time charter coverage for the Partnership’s fleet is calculated by dividing the fleet contracted days on the basis of the earliest estimated delivery and redelivery dates prescribed in the Partnership’s current time charter contracts, net of scheduled class survey repairs, by the number of expected Available Days during that period.

(5) The Partnership calculates its estimated contracted revenue backlog by multiplying the contractual daily hire rate by the expected number of days committed under the contracts (assuming earliest delivery and redelivery and excluding options to extend), assuming full utilization. The actual amount of revenues earned and the actual periods during which revenues are earned may differ from the amounts and periods disclosed due to, for example, the early termination or temporary suspension of charters, dry-docking and/or special survey downtime, maintenance projects, off-hire downtime and other factors that result in lower revenues than the Partnership’s estimated contract revenue backlog.

(6) $0.09 billion of the estimated contracted revenue backlog relates to the estimated portion of the hire contained in certain time charter contracts with Yamal Trade Pte. Ltd., which represents the operating expenses of the respective vessels and is subject to yearly adjustments on the basis of the actual operating costs incurred within each year. The actual amount of revenues earned in respect of such variable hire rate may therefore differ from the amounts included in the estimated contracted revenue backlog due to the yearly variations in the respective vessel’s operating costs.

Russian Sanctions Developments

Due to the ongoing Russian war with Ukraine, the United States (“U.S.”), the European Union (“E.U.”), the United Kingdom (the “U.K.”) and other countries and organizations have publicly announced and enacted extensive sanctions against Russia to impose severe economic pressure on the Russian economy and government.

On October 23, 2025, the E.U. adopted the 19th package of sanctions (the “19th Package”), which prohibits the purchase, import or transfer, directly or indirectly, by E.U. persons and non-E.U. persons with an E.U.-nexus, of LNG that originates in Russia or is exported from Russia (the “LNG Prohibition”). The LNG Prohibition applies from January 1, 2027 with respect to supply contracts with a duration exceeding one year (“Long Term Contracts”) that were executed before June 17, 2025 and that have not since been amended, other than by amendments falling within specified categories.

On July 23, 2026, the E.U. amended the 19th Package with the adoption of the 21st package of sanctions (the “21st Package”). The 21st Package introduced an exemption to the LNG Prohibition, initially until July 25, 2027, and thereafter for successive periods of one year, unless the Council of the E.U. (the “E.U. Council”), following an annual review, decides otherwise. The exemption applies to transfers of LNG destined for third countries, pursuant to Long Term Contracts that were executed before February 24, 2022 and that have not since been amended, other than by amendments falling within specified categories, provided that, the volume of LNG transferred each year under the relevant contract does not exceed the yearly volume of LNG transferred in 2025 under such contract (the “Legacy Contract Derogation”).

Separately, on May 20, 2026, the U.K. enacted the Russia (Sanctions) (EU Exit) (Amendment) Regulations 2026, which prohibit U.K. persons from providing or facilitating maritime transportation services for Russian-origin LNG, including carriage to third countries, subject to limited exceptions and licensing arrangements. The U.K. prohibition will apply beginning January 1, 2027 with respect to certain Long-Term Contracts that were executed before June 17, 2025 and that have not since been amended, other than by amendments falling within specified categories.

One of our charterers, Yamal Trade Pte. Ltd. (the “Charterer”), employs two of our vessels, the Yenisei River and Lena River, on existing Long Term Contracts that extend to 2033 and 2034, respectively (the “Yamal Charters”). These vessels, since commencement of the Yamal Charters, have been engaged in the transportation of LNG produced in Russia for discharge at destinations worldwide in compliance with applicable sanctions regulations.

We believe that the transportation of LNG under the Yamal Charters to destinations outside the E.U. currently falls within the Legacy Contract Derogation and, accordingly, are outside the scope of the LNG Prohibition. However, there can be no assurance that our interpretation of the Legacy Contract Derogation is correct, or that regulatory authorities or our counterparties will agree with our interpretation. Furthermore, there can be no assurance that the transportation of LNG under the Yamal Charters will continue to meet the requirements of the Legacy Contract Derogation, including with respect to the yearly volume limitation, or that the E.U. Council will not decide, following an annual review, to shorten or terminate the Legacy Contract Derogation, or that sanctions regulations will not be further implemented, amended, or expanded to restrict the transportation of Russian-origin LNG. These risks are outside of our control, and if one or more of these events were to occur, our vessels would be restricted from transporting LNG originating in or exported from Russia, which would affect the Charterer’s ability to continue employing the vessels in the manner currently conducted. Notwithstanding the foregoing, we believe the Yamal Charters would remain enforceable, however, the Charterer may not agree with our interpretation, which could result in disputes, non-performance, litigation or early termination of the Yamal Charters, among other things. In addition, sanctions may be extended, amended or interpreted in ways that require the early termination of the Yamal Charters, or give rise to rights of the Charterer, including the purchase option exercisable on a sanctions event described in our interim financial statements.

Furthermore, as a result of the U.K. regulations described above, we expect that we will be required to replace certain key service providers currently based in the U.K., with providers established outside the U.K. There can be no assurance that replacement services will be available on comparable terms, or at all. Any inability to obtain such services, or delay in obtaining them, could disrupt the operation of the affected vessels, result in additional costs or periods of off-hire or affect our ability to perform our obligations under the Yamal Charters or to comply with covenants in our debt agreements.

Our fleet consists of only six LNG carriers and we derive all of our revenues from a limited number of charterers. For the six-month period ended June 30, 2026, the Charterer accounted for 34.5% of our total revenues. The loss of revenue under either or both of the Yamal Charters would have a material adverse effect on our business, results of operations, financial condition and ability to make distributions to our unitholders, and could result in an event of default under our debt agreements.
Other than as described above in relation to the U.K. regulations, applicable U.S., U.K. and E.U. sanctions regimes that are in effect as of today’s date do not materially affect our business, operations or financial condition and, to our knowledge, our counterparties are currently performing their obligations under their respective time charters in compliance with such sanctions regulations. We closely monitor the applicability of sanctions regulations on us and our counterparties, and the potential impact of economic sanctions on our existing commercial arrangements, including the Yamal Charters. The full impact of the commercial and economic consequences of the Russian war with Ukraine is uncertain at this time. The E.U. and U.K. sanctions regulations described above or any further development in sanctions, or escalation of the Ukraine war and other geopolitical events and conflicts more generally may have a material adverse impact on our business, financial condition, results of operations, our ability to make distributions to unitholders or our ability to comply with the covenants in our debt agreements. Sanctions have been expanded over time and may continue to evolve and could ultimately restrict or prevent the performance of certain contractual obligations under our charters.

Please see the section of this press release entitled “Forward Looking Statements”. Please also see the risk factors we describe in our Annual Report on Form 20-F for the year ended December 31, 2025, including without limitation, the risk factors entitled “We currently derive all our revenue and cash flow from a limited number of charterers and the loss of any of these charterers could cause us to suffer losses or otherwise adversely affect our business,” “Any charter termination would likely have a material adverse effect on our business, financial condition, results of operations and cash flows,” “If our vessels call on ports located in countries or territories that are the subject of sanctions or embargoes imposed by the United States government or other governmental authorities, it could result in the imposition of monetary fines or penalties and adversely affect our reputation and the market for our securities” and “We may be subject to litigation that could have an adverse effect on us.”

Slide Presentation:

The slide presentation on the second quarter ended June 30, 2026 financial results will be available in PDF format, accessible on the Partnership’s website www.dynagaspartners.com.

About Dynagas LNG Partners LP

Dynagas LNG Partners LP. (NYSE: DLNG) is a master limited partnership that owns liquefied natural gas (LNG) carriers employed on multi-year charters. The Partnership’s current fleet consists of six LNG carriers, with an aggregate carrying capacity of approximately 914,000 cubic meters.

Visit the Partnership’s website at www.dynagaspartners.com. The Partnership’s website and its contents are not incorporated into and do not form a part of this release.

Contact Information:
Dynagas LNG Partners LP
Attention: Michael Gregos
Tel. +30 210 8917960
Email: [email protected] 

Investor Relations / Financial Media:
Nicolas Bornozis
Markella Kara
Capital Link, Inc.
230 Park Avenue, Suite 1540
New York, NY 10169
Tel. (212) 661-7566
E-mail: [email protected]

Forward-Looking Statements

Matters discussed in this press release may constitute forward-looking statements. The Private Securities Litigation Reform Act of 1995 provides safe harbor protections for forward-looking statements in order to encourage companies to provide prospective information about their business. Forward-looking statements include statements concerning plans, objectives, goals, strategies, future events or performance, and underlying assumptions and other statements, which are other than statements of historical facts.

The Partnership desires to take advantage of the safe harbor provisions of the Private Securities Litigation Reform Act of 1995 and is including this cautionary statement in connection with this safe harbor legislation. The words “believe,” “anticipate,” “intends,” “estimate,” “forecast,” “plan,” “potential,” “project,” “will,” “may,” “should,” “expect,” “expected,” “pending” and similar expressions identify forward-looking statements. These forward-looking statements are not intended to give any assurance as to future results and should not be relied upon.

The forward-looking statements in this press release are based upon various assumptions and estimates, many of which are based, in turn, upon further assumptions, including without limitation, examination by the Partnership’s management of historical operating trends, data contained in its records and other data available from third parties. Although the Partnership believes that these assumptions were reasonable when made, because these assumptions are inherently subject to significant uncertainties and contingencies which are difficult or impossible to predict and are beyond the Partnership’s control, the Partnership cannot assure you that it will achieve or accomplish these expectations, beliefs or projections.

In addition to these important factors, other important factors that, in the Partnership’s view, could cause actual results to differ materially from those discussed, expressed or implied, in the forward-looking statements include, but are not limited to, the strength of world economies and currency fluctuations, general market conditions, including fluctuations in charter rates, ownership days, and vessel values, changes in supply of and demand for liquefied natural gas (LNG) shipping capacity, changes in the Partnership’s operating expenses, including bunker prices, drydocking and insurance costs, the market for the Partnership’s vessels, the early termination of Partnership’s charters and the Partnership’s inability to replace assets and/or long-term contracts, the availability of financing and refinancing, changes in governmental laws, rules and regulations or actions taken by regulatory authorities, economic, regulatory, political and governmental conditions that affect the shipping and the LNG industry, potential liability from pending or future litigation, and potential costs due to environmental damage and vessel collisions, general domestic and international political conditions, potential disruption of shipping routes due to accidents, political events, or international hostilities, geopolitical events including ongoing conflicts and hostilities in the Middle East and other regions throughout the world and the global response to such conflicts and hostilities, changes in tariffs, trade barriers, and embargos, including uncertainty regarding the scope, legitimacy, and durability of existing and future tariff measures by the U.S. and the effects of retaliatory tariffs and countermeasures from affected countries, vessel breakdowns, instances of off-hires, the length and severity of epidemics and pandemics, the impact of public health threats and outbreaks of other highly communicable diseases, the amount of cash available for distribution, and other important factors, including those the Partnership describes from time to time in the reports it files with the U.S. Securities and Exchange Commission (the “SEC”). Due to the ongoing war between Russia and Ukraine, the United States, the United Kingdom, the European Union, and other countries and organizations have announced and enacted numerous sanctions against Russia to impose severe economic pressure on the Russian economy and government. The full impact of the commercial and economic consequences of the Russian war with Ukraine is uncertain at this time. For further information, please see “Russian Sanctions Developments” herein. Partnership cannot provide any assurance that current applicable sanctions, any further development in sanctions, or escalation of the Ukraine war and other geopolitical events and conflicts more generally, will not have a significant impact on its business, financial condition, results of operations, or ability to make distributions to unitholders.

Please see the Partnership’s filings with the SEC for a more complete discussion of these and other risks and uncertainties. The information set forth herein speaks only as of the date hereof.

The Partnership undertakes no obligation, and specifically declines any obligation, to update any forward-looking statements, whether as a result of new information, future events, or otherwise, except as may be required under applicable laws. New factors emerge from time to time, and it is not possible for the Partnership to predict all of these factors which may adversely affect its results. Further, the Partnership cannot assess the effect of each such factor on its business or the extent to which any factor, or combination of factors, may cause actual results to be materially different from those contained in any forward-looking statement. If one of more forward-looking statements are updated, no inference should be drawn that additional updates will be made with respect to those or other forward-looking statements

APPENDIX A

DYNAGAS LNG PARTNERS LP
Condensed Consolidated Statements of Income
 (In thousands of U.S. dollars except units and per unit data) Three Months Ended
June 30, Six Months Ended
June 30,  2026
(unaudited) 2025
(unaudited) 2026
(unaudited) 2025
(unaudited)REVENUES        Voyage revenues$41,188 $38,613 $81,126 $77,720 Other operating revenues from related party 573  —  573  — EXPENSES        Voyage expenses (including related party) (2,889)  (1,549)  (5,980)  (3,289) Vessel operating expenses (8,912)  (7,747)  (19,089)  (16,478) General and administrative expenses (including related party) (407)  (457)  (939)  (971) Management fees -related party (1,740)  (1,690)  (3,462)  (3,361) Depreciation (7,994)  (7,994)  (15,900)  (15,900) Operating income 19,819  19,176  36,329  37,721 Interest and finance costs, net (3,837)  (5,230)  (7,811)  (10,096) Other, net (25)  (237)  (28)  (346) Other income —  —  4,893  — Net income$15,957 $13,709 $33,383 $27,279 Earnings per common unit
(basic and diluted)$0.39 $0.23 $0.82 $0.52 Weighted average number of units outstanding, basic and diluted:        Common units 36,382,011  36,552,642  36,382,011  36,644,628               DYNAGAS LNG PARTNERS LP
Condensed Consolidated Balance Sheets
(Expressed in thousands of U.S. dollars—except for unit data)
       June 30,
2026
(unaudited) December 31,
2025
(unaudited)ASSETS:    Cash and cash equivalents$59,486$41,039Due from related party (current and non-current) 1,350 3,225Other assets 13,718 8,832Vessels, net 717,248 733,148Total assets$791,802$786,244     LIABILITIES    Other financial liabilities, net of deferred financing fees$255,225$277,073Other liabilities 36,435 35,941Due to related party (current and non-current) 546 —Total liabilities$292,206$313,014     PARTNERS’ EQUITY    General partner (35,526 units issued and outstanding as at June 30, 2026 and December 31, 2025) 206 180Common unitholders (36,382,011 units issued and outstanding as at June 30, 2026 and December 31, 2025) 426,174 399,834Series A Preferred unitholders: (3,000,000 units issued and outstanding as at June 30, 2026 and December 31, 2025) 73,216 73,216Total partners’ equity$499,596$473,230     Total liabilities and partners’ equity$791,802$786.244      DYNAGAS LNG PARTNERS LP
Condensed Consolidated Statements of Cash Flows
(Expressed in thousands of U.S. dollars)    Three Months Ended
June 30, Six Months Ended
June 30,  2026  2025  2026  2025   (unaudited) (unaudited)Cash flows from Operating Activities:        Net income:$15,957 $13,709 $33,383 $27,279 Adjustments to reconcile net income to net cash provided by operating activities:        Depreciation 7,994  7,994  15,900  15,900 Amortization of deferred financing fees 116  132  236  267 Deferred revenue amortization (164)  700  (371)  1,393 Amortization of deferred charges 18  54  71  107 Changes in operating assets and liabilities:        Trade accounts receivable 1,148  56  (315)  675 Prepayments and other assets (595)  (3,347)  (936)  (223) Inventories 2  (11)  30  (42) Due from/ to related parties 634  691  2,421  1,440 Deferred charges (120)  4  (120)  4 Trade accounts payable (1,153)  (22)  (1,252)  (32) Accrued liabilities (193)  3,074  179  (827) Accrued interest on Redeemable Preferred Units —  529  —  529 Unearned revenue (2,634)  747  (1,677)  (4,086) Net cash from Operating Activities 21,010  24,310  47,549  42,384          Cash flows from Financing Activities:        Repurchase of common units costs —  (4)  —  (4) Repurchase of common units —  (554)  —  (785) Distributions declared and paid (3,509)  (4,830)  (7,018)  (9,811) Repayment of other financial liabilities (11,042)  (11,042)  (22,084)  (22,084) Net cash used in Financing Activities (14,551)  (16,430)  (29,102)  (32,684)          Net increase in cash and cash equivalents 6,459  7,880  18,447  9,700 Cash and cash equivalents at beginning of the period 53,027  69,976  41,039  68,156 Cash and cash equivalents at end of the period$59,486 $77,856 $59,486 $77,856              
APPENDIX B

Fleet Statistics and Reconciliation of U.S. GAAP Financial Information to Non- GAAP Financial Information

  Three Months Ended
June 30, Six Months Ended
June 30,(expressed in United states dollars except for operational data) 2026  2025  2026  2025   (unaudited) (unaudited)Number of vessels at the end of period 6  6  6  6 Average number of vessels in the period(1) 6  6  6  6 Calendar Days(2) 546.0  546.0  1,086.0  1,086.0 Available Days(3) 546.0  546.0  1,086.0  1,086.0 Revenue earning days(4) 525.5  542.5  1,039.0  1,082.5 Time Charter Equivalent rate(5)$70,145 $67,883 $69,195 $68,537 Fleet Utilization(4) 96.2%  99.4%  95.7%  99.7% Vessel daily operating expenses(6)$16,322 $14,189 $17,577 $15,173  (1) Represents the number of vessels that constituted the Partnership’s fleet for the relevant period, as measured by the sum of the number of days that each vessel was a part of the Partnership’s fleet during the period divided by the number of Calendar Days (defined below) in the period.

(2) “Calendar Days” are the total days that the Partnership possessed the vessels in its fleet for the relevant period.

(3) “Available Days” are the total number of Calendar Days that the Partnership’s vessels were in its possession during a period, less the total number of scheduled off-hire days during the period associated with major repairs or dry-dockings.

(4) The Partnership calculates fleet utilization by dividing the number of its Revenue earning days, which are the total number of Available Days of the Partnership’s vessels net of unscheduled off-hire days (which do not include positioning-repositioning days for which compensation has been received) during a period by the number of Available Days. The shipping industry uses fleet utilization to measure a company’s efficiency in finding employment for its vessels and minimizing the number of days that its vessels are off-hire for reasons such as unscheduled repairs but excluding scheduled off-hires for vessel upgrades, dry-dockings, or special or intermediate surveys.

(5) Time charter equivalent rate (“TCE rate”) is a measure of the average daily revenue performance of a vessel. For time charters, the Partnership calculates TCE rate by dividing total voyage revenues, less any voyage expenses, by the number of Available Days during the relevant time period. Under a time charter, the charterer pays substantially all vessel voyage related expenses. However, the Partnership may incur voyage related expenses when positioning or repositioning vessels before or after the period of a time charter, during periods of commercial waiting time or while off-hire during dry-docking or due to other unforeseen circumstances. The TCE rate is not a measure of financial performance under U.S. GAAP (non-GAAP measure), and should not be considered as an alternative to voyage revenues, the most directly comparable GAAP measure, or any other measure of financial performance presented in accordance with U.S. GAAP. However, the TCE rate is a standard shipping industry performance measure used primarily to compare period-to-period changes in a company’s performance despite changes in the mix of charter types (such as time charters, voyage charters) under which the vessels may be employed between the periods and to assist the Partnership’s management in making decisions regarding the deployment and use of the Partnership’s vessels and in evaluating their financial performance. The Partnership’s calculation of TCE rates may not be comparable to that reported by other companies due to differences in methods of calculation. The following table reflects the calculation of the Partnership’s TCE rates for the periods presented (amounts in thousands of U.S. dollars, except for TCE rates, which are expressed in U.S. dollars, and Available Days):

  Three Months Ended
June 30, Six Months Ended
June 30,  2026  2025  2026  2025 (In thousands of U.S. dollars, except for Available Days and TCE rate) (unaudited) (unaudited)Voyage revenues$41,188 $38,613 $81,126 $77,720 Voyage Expenses * (2,889)  (1,549)  (5,980)  (3,289) Time Charter equivalent revenues$38,299 $37,064 $75,146 $74,431 Available Days 546.0  546.0  1,086.0  1,086 Time charter equivalent (TCE) rate$70,145 $67,883 $69,195 $68,537               *Voyage expenses include commissions of 1.25% paid to Dynagas Ltd., the Partnership’s Manager, and third-party ship brokers, when defined in the charter parties, bunkers, port expenses and other minor voyage expenses.

(6) Daily vessel operating expenses, which include crew costs, provisions, deck and engine stores, lubricating oil, insurance, spares and repairs and flag taxes, are calculated by dividing vessel operating expenses by fleet Calendar Days for the relevant time period.

Reconciliation of Net Income to Adjusted EBITDA

  Three Months Ended
June 30, Six Months Ended
June 30,(In thousands of U.S. dollars) 2026   2025  2026   2025  (unaudited)  (unaudited)Net income$15,957  $13,709 $33,383  $27,279Net interest and finance costs(1) 3,837   5,230  7,811   10,096Depreciation 7,994   7,994  15,900   15,900Amortization of deferred revenue (164)   700  (371)   1,393Amortization of deferred charges 18   54  71   107Other income(2) —   —  (4,893)  —Adjusted EBITDA$27,642  $27,687 $51,901  $54,775 (1) Includes interest and finance costs and interest income, if any.

(2) Includes other income from insurance claims for damages incurred in prior years

The Partnership defines Adjusted EBITDA as earnings before interest and finance costs, net of interest income (if any), taxes (when incurred), depreciation and amortization (when incurred), and non-recurring items (if any). Adjusted EBITDA is used as a supplemental financial measure by management and external users of financial statements, such as investors, to assess the Partnership’s operating performance.

The Partnership believes that Adjusted EBITDA assists its management and investors by providing useful information that increases the ability to compare the Partnership’s operating performance from period-to-period and against that of other companies in its industry that provide Adjusted EBITDA information. This increased comparability is achieved by excluding the potentially disparate effects between periods or against companies of interest, other financial items, depreciation and amortization and taxes, which items are affected by various and possible changes in financing methods, capital structure and historical cost basis and which items may significantly affect Net Income between periods. The Partnership believes that including Adjusted EBITDA as a measure of operating performance benefits investors in (a) selecting between investing in the Partnership and other investment alternatives and (b) monitoring the Partnership’s ongoing financial and operational strength. Adjusted EBITDA is not intended to and does not purport to represent cash flows for the period, nor is it presented as an alternative to operating income. Further, Adjusted EBITDA is not a measure of financial performance under U.S. GAAP and does not represent and should not be considered as an alternative to Net Income, operating income, cash flow from operating activities or any other measure of financial performance presented in accordance with U.S. GAAP. Adjusted EBITDA excludes some, but not all, items that affect Net Income and these measures may vary among other companies. Therefore, Adjusted EBITDA, as presented above, may not be comparable to similarly titled measures of other businesses because they may be defined or calculated differently by those other businesses. It should not be considered in isolation or as a substitute for a measure of performance prepared in accordance with GAAP. Any non-GAAP measures should be viewed as supplemental to, and should not be considered as alternatives to, GAAP measures including, but not limited to net earnings (loss), operating profit (loss), cash flow from operating, investing and financing activities, or any other measure of financial performance or liquidity presented in accordance with GAAP.

Reconciliation of Net Income to Adjusted Net Income available to common unitholders and Adjusted Earnings per common unit

 Three Months Ended
June 30, Six Months Ended
June 30,(In thousands of U.S. dollars except for units and per unit data) 2026   2025   2026   2025   (unaudited)  (unaudited)Net Income$15,957  $13,709  $33,383  $27,279 Amortization of deferred revenue (164)   700   (371)   1,393 Amortization of deferred charges 18   54   71   107 Other income —   —   (4,893)   — Adjusted Net Income$15,811  $14,463  $28,190  $28,779 Less: Adjusted Net Income attributable to preferred unitholders and general partner (1,701)   (3,143)   (3,399)   (6,331) Less: Deemed dividend on Series B Preferred Units —   (2,031)   —   (2,031) Adjusted Net Income available to common unitholders$14,110  $9,289  $24,791  $20,417             Weighted average number of common units outstanding, basic and diluted: 36,382,011   36,552,642   36,382,011   36,644,628 Adjusted Earnings per common unit, basic and diluted$0.39  $0.25  $0.68  $0.56                  Adjusted Net Income represents net income before non-recurring expenses (if any), charter hire amortization related to time charters with escalating time charter rates, amortization of deferred charges, and other income. Adjusted Net Income available to common unitholders represents the common unitholders interest in Adjusted Net Income for each period presented. Adjusted Earnings per common unit represents Adjusted Net Income available to common unitholders divided by the weighted average common units outstanding during each period presented.

Adjusted Net Income, Adjusted Net Income available to common unitholders and Adjusted Earnings per common unit, basic and diluted, are not recognized measures under U.S. GAAP and should not be regarded as substitutes for net income and earnings per unit, basic and diluted. The Partnership’s definitions of Adjusted Net Income, Adjusted Net Income available to common unitholders and Adjusted Earnings per common unit, basic and diluted, may not be the same at those reported by other companies in the shipping industry or other industries. The Partnership believes that the presentation of Adjusted Net Income and Adjusted Net Income available to common unitholders and Adjusted Earnings per common unit, basic and diluted is useful to investors because these measures facilitate the comparability and the evaluation of companies in the Partnership’s industry. In addition, the Partnership believes that Adjusted Net Income is useful in evaluating its operating performance compared to that of other companies in the Partnership’s industry because the calculation of Adjusted Net Income generally eliminates the accounting effects of items which may vary for different companies for reasons unrelated to overall operating performance. The Partnership’s presentation of Adjusted Net Income, Adjusted Net Income available to common unitholders and Adjusted Earnings per common unit does not imply, and should not be construed as an inference, that its future results will be unaffected by unusual or non-recurring items and should not be considered in isolation or as a substitute for a measure of performance prepared in accordance with GAAP.

Investors interested in stocks from the Oil and Gas - Exploration and Production - United States sector have probably already heard of Kolibri Global Energy Inc. (KGEI - Free Report) and Cheniere Energy (LNG - Free Report) . But which of these two stocks presents investors with the better value opportunity right now? Let's take a closer look.

There are plenty of strategies for discovering value stocks, but we have found that pairing a strong Zacks Rank with an impressive grade in the Value category of our Style Scores system produces the best returns. The proven Zacks Rank puts an emphasis on earnings estimates and estimate revisions, while our Style Scores work to identify stocks with specific traits.

Currently, Kolibri Global Energy Inc. has a Zacks Rank of #2 (Buy), while Cheniere Energy has a Zacks Rank of #3 (Hold). The Zacks Rank favors stocks that have recently seen positive revisions to their earnings estimates, so investors should rest assured that KGEI has an improving earnings outlook. However, value investors will care about much more than just this.

Value investors also tend to look at a number of traditional, tried-and-true figures to help them find stocks that they believe are undervalued at their current share price levels.

Our Value category highlights undervalued companies by looking at a variety of key metrics, including the popular P/E ratio, as well as the P/S ratio, earnings yield, cash flow per share, and a variety of other fundamentals that have been used by value investors for years.

KGEI currently has a forward P/E ratio of 8.91, while LNG has a forward P/E of 47.13. We also note that KGEI has a PEG ratio of 0.89. This figure is similar to the commonly-used P/E ratio, with the PEG ratio also factoring in a company's expected earnings growth rate. LNG currently has a PEG ratio of 3.14.

Another notable valuation metric for KGEI is its P/B ratio of 1.01. The P/B is a method of comparing a stock's market value to its book value, which is defined as total assets minus total liabilities. By comparison, LNG has a P/B of 5.33.

These are just a few of the metrics contributing to KGEI's Value grade of A and LNG's Value grade of C.

KGEI has seen stronger estimate revision activity and sports more attractive valuation metrics than LNG, so it seems like value investors will conclude that KGEI is the superior option right now.

TotalEnergies (TTEF.PA) will sell a 9.1% stake in the Papua LNG joint venture to its partners and ​hand the project's operatorship to ExxonMobil (XOM.N), the French energy major said ​on Monday.

The company, which co-owns the project with Exxon, Santos, Kumul ⁠Petroleum/MRDC and ENEOS Xplora, said it would sell shares to its partners in ​proportion to their existing interests, while retaining a 20% stake. It did not ​provide a sale price.

TotalEnergies also said it was nearing a final investment decision on the liquefied natural gas facilities, with contractual and commercial hurdles having now been cleared. CEO Patrick Pouyanné ​had said in July he was targeting a final decision by November.

Papua LNG is ​part of TotalEnergies' portfolio of projects to grow lower-cost LNG supplies, producing 5.6 million metric ‌tons ⁠per year (Mtpa) from the Elk and Antelope fields in Papua New Guinea's Gulf Province, mainly for Asian buyers.

Exxon, which already runs the neighbouring PNG LNG plant, will take over as the operator of the project. TotalEnergies' offtake share, which gives ​it access to 1.5 ​Mtpa of LNG ⁠for its portfolio, remains unchanged.

TotalEnergies has completed the tendering process for engineering, procurement and construction work for the project, it ​said, with contracts now pending its partners' approval.

Close to $4 billion ​has been ⁠achieved in cost savings since 2024 through rebidding those contracts and optimising the project design, bringing capital spending down to around $14 billion, it added.

The companies have also ⁠finalised an ​amended gas agreement with Papua New Guinea's ​government and set up an LNG marketing joint venture with Kumul Petroleum to sell 2.4 Mtpa of ​the project's 5.6 Mtpa output.

 | Source: Dynagas LNG Partners LP

ATHENS, Greece, Sept. 02, 2026 (GLOBE NEWSWIRE) -- Dynagas LNG Partners LP (NYSE: “DLNG”) (“Dynagas Partners” or the “Partnership”), an owner of LNG carriers, today announced that it will release its financial results for the second quarter and six months ended June 30, 2026, before market opens in New York on Tuesday, September 8, 2026.

An accompanying slide presentation for the three-month and six-month periods will be available on the Dynagas LNG Partners website under the Presentations section of the Investor Relations page.

About Dynagas LNG Partners LP

Dynagas LNG Partners LP (NYSE: DLNG) is a master limited partnership which owns LNG carriers employed on multi-year charters. The Partnership’s current fleet consists of six LNG carriers, with aggregate carrying capacity of approximately 914,000 cubic meters.

Visit the Partnership’s website at www.dynagaspartners.com.

Contact Information:
Dynagas LNG Partners LP
Attention: Michael Gregos
Tel. +30 210 8917960
Email: [email protected]

Investor Relations/ Financial Media
Nicolas Bornozis/Markella Kara
Capital Link, Inc.
230 Park Avenue, Suite 1540
New York, NY 10169
Tel. (212) 661-7566
E-mail: [email protected]

 | Source: Dynagas LNG Partners LP

ATHENS, Greece, Sept. 01, 2026 (GLOBE NEWSWIRE) -- Dynagas LNG Partners LP (NYSE: “DLNG”) (“Dynagas Partners” or the “Partnership”), an owner of LNG carriers, today announced that it will release its financial results for the second quarter and six months ended June 30, 2026, after market closes in New York on Monday, September 7, 2026.

An accompanying slide presentation for the three-month and six-month periods will be available on the Dynagas LNG Partners website under the Presentations section of the Investor Relations page.

About Dynagas LNG Partners LP

Dynagas LNG Partners LP (NYSE: DLNG) is a master limited partnership which owns LNG carriers employed on multi-year charters. The Partnership’s current fleet consists of six LNG carriers, with aggregate carrying capacity of approximately 914,000 cubic meters.

Visit the Partnership’s website at www.dynagaspartners.com.

Contact Information:
Dynagas LNG Partners LP
Attention: Michael Gregos
Tel. +30 210 8917960
Email: [email protected]

Investor Relations/ Financial Media
Nicolas Bornozis/Markella Kara
Capital Link, Inc.
230 Park Avenue, Suite 1540
New York, NY 10169
Tel. (212) 661-7566
E-mail: [email protected]

1.72K Followers

Analyst’s Disclosure: I/we have a beneficial long position in the shares of GLNG, VG either through stock ownership, options, or other derivatives. I wrote this article myself, and it expresses my own opinions. I am not receiving compensation for it (other than from Seeking Alpha). I have no business relationship with any company whose stock is mentioned in this article.

Seeking Alpha's Disclosure: Past performance is no guarantee of future results. No recommendation or advice is being given as to whether any investment is suitable for a particular investor. Any views or opinions expressed above may not reflect those of Seeking Alpha as a whole. Seeking Alpha is not a licensed securities dealer, broker or US investment adviser or investment bank. Our analysts are third party authors that include both professional investors and individual investors who may not be licensed or certified by any institute or regulatory body.

Q2 adjusted EBITDA reached $127.4 million, reinforcing evidence that Golar's FLNG strategy is translating into stronger reported earnings. The fourth FLNG unit expands future capacity by roughly 41% and strengthens Golar's long-term growth optionality beyond the existing contracted backlog. Hilli's 20-year Argentina contract adds substantial long-duration earnings visibility, while Gimi's full contribution supports the current EBITDA run rate.

Investment reflects 10.5% equity interest in Operating Aerospace-Spec LNG Producer Positioned for the U.S. Space Launch Buildout  | Source: Datacentrex Inc.

Eagle LNG produces high-methane, aerospace-specification LNG required by the next generation of American reusable launch vehiclesInvestment is being made concurrently with, and at the same value per unit as, a $10 million commitment by an affiliate of The Energy & Minerals Group (“EMG”). Funds managed by EMG are Eagle LNG’s controlling sponsor and an existing investor in the business SALT LAKE CITY, Aug. 31, 2026 (GLOBE NEWSWIRE) -- Datacentrex, Inc. (“Datacentrex” or the “Company”) (Nasdaq: DTCX) today announced that it has entered into a Common Unit Purchase Agreement and invested $30 million in ELNG Equity LLC (“ELNG”), the equity holding company of Eagle LNG Partners LLC (“Eagle LNG”), acquiring $30 million of Class A Common Units. Eagle LNG is a vertically integrated producer of liquefied natural gas and a qualified supplier of the aerospace-specification liquid methane used to fuel next-generation American launch vehicles.

An Operating Business, Not a Development Project

Eagle LNG has been producing and delivering LNG since 2017 and serves a contracted customer base across space propulsion, marine bunkering, island utility and industrial end-markets under long-term take-or-pay supply agreements with a weighted average tenor of approximately 15 years. Since 2018 it has completed more than 700 LNG bunkering operations, both ship-to-shore and ship-to-ship, without incident.

“We are focused on companies producing real revenue in ultra-high-growth sectors, and we intend to be at the forefront of them,” said Parker Scott, Chief Executive Officer of Datacentrex. “Eagle LNG is not a concept. It has been producing and delivering LNG since 2017 and it is already under contract with a leading space propulsion customer. The United States is setting out to multiply its launch cadence several times over this decade, and every one of those vehicles has to be fueled. We would rather own a position in the supply chain underneath that growth than try to pick which vehicle wins.”

About Datacentrex, Inc.

Datacentrex, Inc. is a diversified technology-driven enterprise operating a digital asset mining business across high-growth sectors including digital-asset infrastructure, data-center operations, and energy and space-launch infrastructure. Datacentrex, Inc. intends to pursue selective investments, partnerships, and acquisitions to drive innovation and value creation. For additional information, please refer to the Company’s filings with the U.S. Securities and Exchange Commission, which are available at www.sec.gov.

Visit Datacentrex’s investor relations website at https://ir.datacentrex.com/.

About Eagle LNG Partners

Eagle LNG Partners is a Jacksonville, Florida–based developer and operator of small-scale LNG infrastructure serving space propulsion, marine bunkering, island utility and industrial customers across the southeastern United States and the Caribbean. Eagle LNG was formed in 2013 and is controlled by The Energy & Minerals Group.

Forward-Looking Statements Disclaimer

This press release contains certain forward-looking statements within the meaning of the safe harbor provisions of the Private Securities Litigation Reform Act of 1995. All statements other than statements of historical fact included in this press release, including statements regarding the anticipated benefits of the investment; Eagle LNG’s planned expansion projects and their expected cost, timing and capacity impact; the expected commencement of contract volumes; projected growth in space propulsion, launch cadence, marine bunkering or other LNG demand; the effect of governmental policy on commercial space activity; Eagle LNG’s ability to convert unfilled demand or rights of first refusal into contracted volumes; the potential for future strategic transactions involving Eagle LNG; and Datacentrex’s future financial condition, results of operations, business operations and business prospects, are forward-looking statements. These statements are identified by the use of the words “could,” “believe,” “anticipate,” “intend,” “estimate,” “expect,” “may,” “continue,” “predict,” “potential,” “project” and similar expressions that are intended to identify forward-looking statements.

All forward-looking statements are subject to important factors, risks, uncertainties, and assumptions, including industry and economic conditions that could cause actual results to differ materially from those described in the forward-looking statements. Such factors, risks, uncertainties and assumptions include, but are not limited to: the illiquid, non-controlling nature of the Company’s interest and the absence of any public market for the Class A Common Units, and the resulting risk of loss of all or a portion of the investment; the absence of any obligation or committed timetable for ELNG to pursue an initial public offering or other liquidity event, and the possibility that no such transaction occurs, that it is delayed or completed on terms unfavorable to existing holders, or that it does not result in liquidity for the Company’s units, which may remain subject to lock-up, conversion and transfer restrictions; the Company’s limited ability to influence Eagle LNG’s management, strategy, capital structure or distribution policy; Eagle LNG’s substantial existing indebtedness and preferred equity, and its ability to service, refinance or repay those obligations; delays, cost overruns or permitting, siting or construction risk affecting the Talleyrand second berth, the Maxville de-bottlenecking program, or any future liquefaction capacity; the possibility that de-bottlenecking does not achieve expected production capacity; customer concentration and the commencement, renewal, modification, non-performance or early termination of customer contracts, including termination rights exercisable on limited notice; the fact that a right of first refusal does not obligate any counterparty to purchase any volumes; the early-stage and capital-intensive nature of the commercial space launch industry and its dependence on third-party launch cadence, vehicle qualification and government programs outside Eagle LNG’s control; the possibility that announced governmental objectives regarding launch cadence are not achieved, are modified, or do not translate into demand for Eagle LNG’s products; volatility in natural gas, LNG and competing marine fuel prices; changes in tax credits, tariffs, export authorizations and other governmental policies affecting LNG; the reliance of statements in this release regarding Eagle LNG on information provided by Eagle LNG, which the Company has not independently verified; the effect of the investment on the Company’s liquidity and capital resources; volatility in the prices of Dogecoin, Litecoin, Bitcoin and other digital assets and increases in Scrypt network difficulty; and volatility of Datacentrex’s stock price.

Forward-looking statements also are affected by the risk factors described in the Company’s filings with the U.S. Securities and Exchange Commission (the “SEC”), including in the Company’s Annual Report on Form 10-K, Quarterly Reports on Form 10-Q, and Current Reports on Form 8-K. Investors and security holders are urged to read these documents free of charge on the SEC’s website at http://www.sec.gov. The risks and uncertainties that Datacentrex has described are not the only ones Datacentrex faces. Additional risks and uncertainties not presently known to Datacentrex or that Datacentrex currently deems immaterial may also affect Datacentrex’s operations. All forward-looking statements speak only as of the date of this press release. You should not place undue reliance on these forward-looking statements. Except as required by law, Datacentrex undertakes no obligation to update or revise publicly any forward-looking statements, whether as a result of new information, future events or otherwise, after the date on which the statements are made.

This press release does not constitute an offer to sell or the solicitation of an offer to buy any security.

Company Contact

Datacentrex Investor Relations

[email protected]

800-403-6150

PARIS--(BUSINESS WIRE)--As mentioned on the occasion of the presentation of the 2nd Quarter 2026 Results, TotalEnergies (Paris:TTE) (LSE:TTE) (NYSE:TTE) confirms that the transfer of its 10% interest in Arctic LNG 2 to NordLine (a Novatek subsidiary) has been completed. TotalEnergies is therefore no longer a shareholder in Arctic LNG 2. As part of the transfer agreement, TotalEnergies retains its rights to be reimbursed by Arctic LNG 2 for its share of the loans provided by the shareholders to.

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Seeking Alpha's Disclosure: Past performance is no guarantee of future results. No recommendation or advice is being given as to whether any investment is suitable for a particular investor. Any views or opinions expressed above may not reflect those of Seeking Alpha as a whole. Seeking Alpha is not a licensed securities dealer, broker or US investment adviser or investment bank. Our analysts are third party authors that include both professional investors and individual investors who may not be licensed or certified by any institute or regulatory body.

Key Takeaways LNG raised 2026 adjusted EBITDA guidance to $7.9-$8.4 billion as operating trends improved.LNG volumes rose 22.2% year over year, helping lift adjusted EBITDA 27.4% to $1.8 billion.LNG's expansion pipeline adds growth potential, while capital needs and valuation raise execution risks. Cheniere Energy, Inc. (LNG - Free Report) shares have gained 16.1% in the past three months, leaving investors to weigh improving operating trends against a richer valuation. Higher LNG volumes, stronger margins and raised 2026 guidance support the fundamental case.

Image Source: Zacks Investment Research

The expansion pipeline adds another potential growth leg, but capital spending, regulatory dependencies and rising global LNG supply limit room for execution mistakes.

Cheniere's Rally Meets Stronger 2026 FundamentalsCheniere raised its 2026 consolidated adjusted EBITDA guidance to $7.9-$8.4 billion from $7.25-$7.75 billion. Distributable cash flow guidance increased to $5.3-$5.8 billion from $4.75-$5.25 billion.

Management tied the revision to improved reliability, accelerated Stage 3 train start-ups, higher marketing margins and optimization gains. Those developments help frame the optimism surrounding the shares without establishing a direct cause for the three-month advance.

LNG Volume Growth Supports Cheniere's Operating MomentumSecond-quarter LNG volumes loaded reached 672 trillion British thermal units, up 22.2% year over year, while 184 cargoes were exported versus 154 a year earlier. Cheniere also posted quarterly production records at both Corpus Christi and Sabine Pass.

Higher volumes and stronger margins lifted consolidated adjusted EBITDA to $1.8 billion from $1.42 billion, an increase of 27.4%. The combination of higher throughput and margin improvement gives the recent operating momentum a firmer earnings base.

Cheniere's Brownfield Projects Add a Growth RunwayCorpus Christi Stage 3 was 98.4% complete at June 30, with the first six midscale trains operational and Train 7 in construction and commissioning. Train 7 was expected to reach substantial completion in the second half of 2026.

Midscale Trains 8 and 9 were 48.3% complete and remain targeted for the second half of 2028. At Sabine Pass, Phase 1 is designed to add more than 6 million tons per annum through Train 7 and a boil-off gas reliquefaction unit, extending Cheniere's brownfield growth runway.

LNG Valuation Leaves Less Room for Execution SlipsThe rally has pushed Cheniere to 2.57X forward 12-month sales, above its five-year median of 2.08X.

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That premium leaves less room for construction delays, weaker project economics or softer contracting conditions.

Expansion is also capital intensive. Cheniere invested about $1.1 billion of growth capital in the second quarter, while key expansion projects still depend on regulatory approvals and acceptable commercial arrangements. Industry competition is increasing as Venture Global, Inc. (VG - Free Report) advances CP2 LNG and NextDecade Corporation (NEXT - Free Report) builds five Rio Grande LNG trains with about 30 million tons per annum of expected capacity.

Cheniere's Momentum Score Backs a Balanced ViewCheniere's operating progress and expansion visibility remain constructive, but the current valuation and execution requirements argue against treating the recent rally as a one-way signal. The setup supports a balanced assessment of further upside.

The stock currently carries a Zacks Rank #3 (Hold), along with a VGM Score of B. Its Momentum Score of A is consistent with favorable recent price trends, while the Value Score of C and Growth Score of C point to a less clear-cut case on valuation and growth characteristics. Together, those readings support a measured stance after the three-month advance. You can see the complete list of today’s Zacks #1 Rank stocks here.

On CNBC’s “Halftime Report Final Trades,” Stephen Weiss, chief investment officer and managing partner of Short Hills Capital Partners, picked Cisco Systems, Inc. (NASDAQ:CSCO).

On the earnings front, Cisco, on Aug. 12, reported fourth-quarter revenue of $17.25 billion, beating analyst estimates of $16.82 billion, according to Benzinga Pro. The networking equipment company reported adjusted earnings of $1.22 per share for the quarter, beating analyst estimates of $1.17 per share.

Jim Lebenthal, partner and chief market strategist at Cerity Partners, named Cheniere Energy, Inc. (NYSE:LNG) as his final trade.

Lending support to his choice, TD Cowen analyst Jason Gabelman, on Aug. 11, maintained Cheniere Energy with a Buy and raised the price target from $280 to $290.

Don’t forget to check out our premarket coverage here

Shannon Saccocia, Neuberger, recommended iShares U.S. Utilities ETF (NYSE:IDU).

Joseph M. Terranova, senior managing director for Virtus Investment Partners, named Merck & Co., Inc. (NYSE:MRK) as his final trade.

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Supporting his view, Daiwa Capital analyst Narumi Nakagiri, on Aug. 12, upgraded Merck from Neutral to Outperform and raised the price target from $120 to $143.

Price Action:

Cisco shares gained 1.1% to close at $112.90 on Monday. Cheniere Energy shares fell 1.7% to settle at $266.93 during the session. iShares U.S. Utilities ETF fell 0.3% on Monday. Merck shares rose 0.1% to close at $135.97 on Monday. Photo via Shutterstock

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TORONTO, ON / ACCESS Newswire / August 17, 2026 / LNG Energy Group Corp. (TSXV:LNGE)(TSXV:LNGE.WT)(OTC PINK:LNGNF)(FWB:E26) (the "Company" or "LNG Energy Group") is pleased to announce that, further to its news releases dated May 1, 2026, July 28, 2026 and August 6, 2026, it has completed the first tranche (the "First Tranche") of its previously announced non-brokered private placement financing (the "Private Placement") of units of the Company ("Units"). The Company issued 9,438,071 Units at a price of C$0.05 per Unit for aggregate gross proceeds of approximately C$471,903.

Each Unit consists of one (1) common share of the Company (each, a "Common Share"), and one (1) Common Share purchase warrant (each, a "Warrant"), with each Warrant exercisable to acquire one Common Share at a price of C$0.10 per share for a period of 36 months from the date of issuance.

The First Tranche was completed in accordance with the terms of the partial revocation orders (the "Partial Revocation Orders") issued by the Ontario Securities Commission (the "OSC") on April 23, 2026 and August 6, 2026, each of which partially revoked the failure-to-file cease trade order issued by the OSC against the Company on May 7, 2025 (the "FFCTO") for purposes of permitting the Company to complete the Private Placement.

Prior to closing of the First Tranche, each subscriber of the Private Placement (collectively, the "Subscribers"): (i) received copies of the FFCTO and the Partial Revocation Orders, and (ii) delivered an acknowledgement to the Company confirming that all of the Company's securities, including the Units and the underlying securities issued in connection with the Private Placement, will remain subject to the FFCTO unless and until the FFCTO is fully revoked, and that the granting of the Partial Revocation Orders by the OSC does not guarantee that a full revocation of the FFCTO will be granted in the future.

The First Tranche included subscriptions from insiders of the Company for an aggregate of 1,982,688 Units or approximately C$99,134. This participation by insiders of the Company constitutes "related party transactions" within the meaning of Multilateral Instrument 61-101 - Protection of Minority Shareholders in Special Transactions ("MI 61-101"). For these transactions, the Company has relied on the exemption from the formal valuation requirement contained in Section 5.5(a) of MI 61-101 and has relied on the exemption from the minority shareholder requirements contained in Section 5.7(1)(a) of MI 61-101, as well as the corresponding exemptions contained in Policy 5.9 of the TSX Venture Exchange (the "TSXV").

The Units issued pursuant to the First Tranche are subject to a hold period of four months and one day from the date of issuance in accordance with the policies of the TSXV and applicable securities legislation, which expires on December 15, 2026.

All of the Company's securities, including the Units and underlying securities issued in connection with the Private Placement, will remain subject to the FFCTO unless and until the FFCTO has been fully revoked. The Company intends to use the proceeds from the Private Placement to satisfy its outstanding continuous disclosure obligations and to apply for a full revocation of the FFCTO; however, there can be no assurance that a full revocation order will be obtained.

The closing of the First Tranche of Private Placement remains subject to the final acceptance of the TSXV. The Company anticipates closing a second tranche of the Private Placement on the week commencing on August 24 and may conduct additional closings prior to the expiry of the Partial Revocation Order.

The securities issued pursuant to the Private Placement have not been, nor will they be, registered under the United States Securities Act of 1933, as amended (the "U.S. Securities Act"), or any state securities laws, and may not be offered or sold to, or for the account or benefit of, persons in the United States or U.S. persons absent registration under the U.S. Securities Act and all applicable state securities laws or compliance with the requirements of an exemption therefrom. This news release shall not constitute an offer to sell or the solicitation of an offer to buy nor shall there be any sale of the Units in any jurisdiction in which such offer, solicitation or sale would be unlawful.

About LNG Energy Group

The Company is focused on the acquisition and development of natural gas production and exploration assets in Latin America. For more information, please visit www.lngenergygroup.com.

For more information please contact:

Angel Roa, Chief Financial Officer LNG Energy Group Corp.
Website: www.lngenergygroup.com
Email: [email protected]

Find us on social media:

LinkedIn: https://www.linkedin.com/company/lng-energy-group-inc/
Instagram: @lngenergygroup
X: @LNGEnergyCorp

CAUTIONARY NOTE REGARDING FORWARD-LOOKING INFORMATION:

This news release contains "forward-looking information" and "forward-looking statements" (collectively, "forward-looking statements") within the meaning of applicable Canadian securities laws. All statements other than statements of historical fact are forward-looking statements, and are based on expectations, estimates and projections as at the date of this news release that reflect the current views and/or expectations of management of LNG Energy Group with respect to performance, business and future events. Forward-looking information can often be identified by words such as "may", "will", "would", "could", "should", "believes", "estimates", "projects", "potential", "expects", "plans", "intends", "anticipates", "targeted", "continues", "forecasts", "designed", "goal", or the negative of those words or other similar or comparable words. Forward-looking statements are based on the then-current expectations, beliefs, assumptions, estimates and forecasts about the business and the industry and markets in which LNG Energy Group operates, in light of our experience and perception of historical trends, current conditions and expected future developments, as well as other factors that we believe are appropriate and reasonable in the circumstances, and that while considered reasonable, are subject to known and unknown risks, uncertainties and other factors that may cause actual results to differ materially from those expressed or implied in the forward-looking information. There can be no assurance that such statements will prove to be accurate, and accordingly, readers should not place undue reliance on the forward-looking statements contained in this news release. LNG Energy Group does not undertake any obligation to release publicly any revisions or update any voluntary forward-looking statements, except as required by applicable securities law, whether they change as a result of new information, future events or otherwise.

This news release includes, but is not limited to, forward-looking statements relating to: the timing, terms and completion of the Private Placement, the use of funds from the Private Placement, approval of the Private Placement (including approvals of the TSXV), the Company preparing and filing all outstanding continuous disclosure documents, and the Company applying for and receiving a full revocation of the FFCTO. Forward-looking statements in this press release are based on certain assumptions, namely: the ability of the Company to continue as a going concern, the ability of the Company to complete the Private Placement, the ability of the Company to use the funds from the Private Placement as intended, the ability of the Company to prepare and file all outstanding continuous disclosure documents and the Company's ability to apply for and receive a full revocation of the FFCTO. Forward-looking statements address future events and conditions and therefore involve inherent risks and uncertainties, including, but not limited to: the inability of the Company to complete the Private Placement, the inability of the Company to obtain approval from the TSXV, the inability of the Company to use the funds from the Private Placement for the intended purposes, the inability of the Company to prepare and file all outstanding continuous disclosure documents and the inability of the Company to have the FFCTO fully revoked. The Company's actual decisions, activities, results, performance, or achievement could differ materially from those expressed in, or implied by, such forward- looking statements and accordingly, no assurances can be given that any of the events anticipated by the forward-looking statements will transpire or occur or, if any of them do, what benefits that the Company will derive from them.

Neither the TSX Venture Exchange nor its Regulation Services Provider (as that term is defined in the policies of the TSX Venture Exchange) accepts responsibility for the adequacy or accuracy of this release.

SOURCE: LNG Energy Group Corp.

Key Takeaways Golar LNG posted Q2 EPS of 68 cents, beating estimates and improving year over year.Q2 revenues of $130.5 million outpaced the Zacks Consensus Estimate and improved 72% year over year.GLNG's share of contractual debt at the end of the second quarter increased 31% year over year. Golar LNG Limited (GLNG - Free Report)  reported impressive second-quarter 2026 results, wherein both earnings and revenues surpassed the Zacks Consensus Estimate and improved year over year.

Quarterly earnings of 68 cents per share surpassed the Zacks Consensus Estimate of 30 cents and increased year over year. Revenues of $130.5 million outpaced the Zacks Consensus Estimate of $125 million and improved 72% year over year.

Adjusted EBITDA of $127.36 million improved 159% year over year.

GLNG exited the second quarter of 2026 with cash and cash equivalents of $870.47 million compared with $1.01 billion at the end of the prior quarter. GLNG’s share of contractual debt at the end of the reported quarter increased 31% to $2.68 billion.

GLNG’s board of directors approved a second-quarter 2026 dividend of 25 cents per share. The dividend will be paid on Sept. 2, 2026, to shareholders of record at the close of business on Aug. 24. As of June 30, 2026, GLNG had 102.1 million shares issued and outstanding.

Currently, GLNG sports a Zacks Rank #3 (Hold). You can see the complete list of today’s Zacks #1 Rank (Strong Buy) stocks here.

Q2 Performance of Some Other Stocks Belonging to GLNG's IndustryEni S.p.A.(E - Free Report) reported second-quarter 2026 adjusted earnings of $1.76 per American Depository Receipt, missing the Zacks Consensus Estimate of $1.90 by 7.4%. The bottom line increased 122.8% from the year-ago quarter’s 79 cents. Quarterly revenues of $26.35 billion rose 21.5% year over year and surpassed the consensus estimate of $24 billion by 9.8%.

Higher commodity realizations, production growth and stronger segment profitability supported revenues.

Chevron Corporation(CVX - Free Report) reported second-quarter 2026 adjusted earnings of $6.06 per share, which beat the Zacks Consensus Estimate of $5.80 by 4.5%. The outperformance was driven by higher commodity prices, increased upstream production following the Hess acquisition, stronger refined-product margins and higher sales volumes.

The company generated revenues of $70.06 billion. The metric beat the Zacks Consensus Estimate of $57.53 billion and increased 56.3% year over year.  The increase was primarily driven by a 51.4% year-over-year increase in sales and other operating revenues, along with a 296.5% rise in income from equity affiliates.

3 LNG Stocks to Watch as Iran War ContinuesGolar LNG NASDAQ: GLNG reported higher second-quarter earnings as its floating liquefied natural gas fleet continued to perform above contracted levels, while the company announced a firm order for a fourth FLNG conversion unit expected to be available in 2029.

Chief Executive Officer Karl Fredrik Staubo said the company signed an order for another Mark II FLNG unit at CIMC Raffles in China, the same shipyard constructing the FLNG Esperanza. The fourth unit is expected to deliver in 2029 and, according to Golar, will represent the earliest available global FLNG capacity.

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Are These Liquid Natural Gas Stocks Ready For An Upside Bounce?The order follows interest from prospective charterers and is consistent with Golar's policy of adding capacity after securing long-term commitments for its existing fleet, Staubo said. While the company has not yet announced a charter for the new unit, management said it is in advanced discussions with potential customers across several regions.

Second-Quarter Financial Results Chief Financial Officer Eduardo Maranhão said total operating revenue was $130 million in the second quarter. EBITDA increased about 20% sequentially to $127 million, from $106 million in the first quarter, primarily due to higher commodity-linked earnings from the Hilli FLNG.

Hilli generated $37 million in commodity-linked earnings during the quarter, compared with $10 million in the prior quarter. Net income was $56 million, bringing year-to-date net income to $158 million.

Golar declared a quarterly dividend of $0.25 per share. At quarter-end, the company had approximately $900 million in cash and about $1.8 billion of net interest-bearing debt. In July, Golar closed a $600 million revolving credit facility that remained undrawn, bringing available liquidity to approximately $1.5 billion.

Maranhão said Golar has funded about $1.3 billion of equity toward the Esperanza conversion project. He added that potential financing of Hilli and Esperanza could release approximately $2.3 billion of additional liquidity, with discussions on those financings advancing.

Fleet Performance and Argentina Redeployment Golar said the Gimi FLNG produced 15% above its contracted capacity during the second quarter. Staubo said the unit's performance occurred despite the higher temperatures of the summer period, which can affect liquefaction plants. Management expects high temperatures to continue affecting performance in the third quarter, but said Gimi is still expected to produce meaningfully above its contractual capacity for the year.

The Hilli completed its eight-year contract with Perenco Offshore Cameroon, delivering 100% economic uptime over the life of the contract and 156 cargoes. Its final cargo under the Cameroon contract was delivered July 26.

Hilli is now traveling to Singapore for modifications before beginning a 20-year contract in Argentina during the second half of 2027. Golar expects Hilli to generate annual EBITDA of $285 million before additional commodity-related upside once it begins operations in Argentina. Staubo said the refurbishment and redeployment budget is approximately $350 million from its departure from Cameroon through commissioning in Argentina.

Meanwhile, the FLNG Esperanza conversion was 74% complete, with more than 15 million man-hours worked without lost-time incidents. The project remains on schedule and on budget, with sail-away targeted by the end of 2027 and operations in Argentina expected to begin in the second half of 2028.

Golar said the total six-million-tonne LNG marketing program associated with Argentina is progressing. The first two million tonnes have been sold to Securing Energy for Europe, while multiple offtakers are bidding for the remaining four million tonnes, with additional agreements expected before year-end.

Growth Plans and Fourth FLNG Economics The fourth FLNG unit will increase Golar-controlled liquefaction capacity by 41%, from 8.6 million tonnes to more than 12 million tonnes on a fully delivered basis. The company said its existing Hilli, Gimi and Esperanza contracts provide an EBITDA backlog of $17 billion through 2045, before commodity upside and inflation adjustments.

The fourth unit has a capital expenditure budget of approximately $2.45 billion, compared with approximately $2.2 billion for Esperanza. Staubo said the roughly 10% increase reflects inflation in long-lead equipment, steel prices and currency fluctuations. He said the budget represents an all-in delivered cost, including shipyard EPC work, crew training, bunkering, transportation to the contract site and anticipated mooring systems.

Management said it expects synergies from repeating the Mark II design and constructing overlapping units at the same yard. Golar has secured a donor vessel for the fourth conversion and has also obtained an option for an additional Mark II FLNG at CIMC Raffles.

In addition, Golar signed a letter of intent with Seatrium in Singapore for shipyard slots that could support Mark I or Mark II FLNG conversions. Management said these arrangements could establish a pathway to a fleet of more than seven units, although the company will maintain its policy of having no more than one uncontracted FLNG unit at a time.

Staubo said Golar will not order a fifth unit until it has clear visibility on a long-term charter for the fourth. He described the typical commercial process as progressing from a term sheet or framework agreement to a definitive contract, followed by satisfaction of conditions precedent such as regulatory approvals, export licenses, environmental permits and, in some cases, tax-regime clarification.

Contracted Earnings and Commodity Exposure Maranhão said Golar expects annual run-rate EBITDA of approximately $800 million by 2028 once Gimi, Hilli and Esperanza are operating, excluding commodity upside and inflation adjustments. If the fourth FLNG secures terms broadly comparable to Esperanza, annual EBITDA could rise by about 50% to more than $1.2 billion by 2030, he said.

Under the Hilli and Esperanza charters in Argentina, Golar receives a commodity-linked fee equal to 25% of free-on-board LNG prices above $8 per MMBtu. Golar also owns a 10% interest in Southern Energy S.A., or SESA, providing further commodity exposure.

Maranhão said each $1 per MMBtu above $8 could generate up to approximately $100 million of incremental annual earnings for Golar. Based on current and forward pricing, the company estimates that commodity exposure could add up to $500 million annually during the first three years of SESA operations.

Management said it continues to conduct its previously announced strategic review but will not provide details on its potential outcome or timing unless there is material information to disclose or the board ends the process.

About Golar LNG (NASDAQ:GLNG)Golar LNG Ltd. is a leading owner and operator of liquefied natural gas (LNG) carriers and floating infrastructure. The company specializes in the transportation of LNG on long-term and spot charters for major energy firms around the world. In addition to shipping, Golar LNG has broadened its services to include project development and the conversion of existing carriers into Floating Liquefied Natural Gas (FLNG) and Floating Storage and Regasification Unit (FSRU) vessels.

Since pioneering the first purpose-built FLNG conversion project, Golar LNG has been at the forefront of offshore gas monetization.

This instant news alert was generated by narrative science technology and financial data from MarketBeat in order to provide readers with the fastest reporting and unbiased coverage. Please send any questions or comments about this story to [email protected].

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Should You Invest $1,000 in Golar LNG Right Now?Before you consider Golar LNG, you'll want to hear this.

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Second Quarter financial summary (in thousands of $) Q2 2026 Q2 2025 % Change YTD 2026 YTD 2025 %  Change Net income attributable to Golar LNG Ltd 38,265 15,639 145% 121,843 23,836 411% Total operating revenues 130,479 75,673 72% 268,033 138,175 94% Adjusted EBITDA 1 127,365 49,255 159% 232,941 90,191 158% Golar's share of contractual debt 1 2,681,568 2,048,873 31% 2,681,568 2,048,873 31% Recent highlights Golar LNG Limited (“Golar” or “the Company”) reports Q2 2026 net income attributable to Golar of $38 million inclusive of $29 million of non-cash items1, Adjusted EBITDA1 of $127 million and Total Golar Cash1 of $908 million, before the recently announced Revolving Credit Facility (“RCF”). Final Investment Decision for 4th FLNG: Signed an Engineering, Procurement and Construction (“EPC”) contract with Yantai CIMC Raffles Offshore Limited (“CIMC Raffles”) for a 3.5 MTPA MKII unit with a fully delivered cost of approximately $2.45 billion and improved payment terms compared to the FLNG Esperanza.

Key Takeaways Venture Global's Q2 EPS soared 264.3% y/y to 51 cents as revenues climbed 47.6% to $4.58B.LNG volumes sold rose 41.7%, while Plaquemines supplied 90 of 127 exported cargoes in the quarter.Venture Global raised 2026 adjusted EBITDA guidance to $8.70-$9.10B and cargo outlook to 50--518. Venture Global, Inc. (VG - Free Report) reported second-quarter 2026 earnings of 51 cents per share, beating the Zacks Consensus Estimate of 49 cents by 4.08%. The bottom line skyrocketed 264.3% from 14 cents in the year-ago quarter.

Quarterly revenues rose 47.6% year over year to $4.58 billion and topped the Zacks Consensus Estimate of $4.50 billion by 1.64%. Higher LNG sales volumes, led by Plaquemines commissioning, and stronger LNG sales prices net of feed gas costs drove the results. Venture Global exported 127 cargoes during the quarter.

VG Benefits From Higher LNG Sales VolumesLNG volumes sold increased 41.7% year over year to 466.4 trillion British thermal units, or TBtu, from 329.2 TBtu. Exported LNG volumes rose 44.6% to 478.3 TBtu from 330.8 TBtu.

Plaquemines accounted for 90 cargoes, while Calcasieu Pass contributed 37. The company also exported its 1,000th cargo across its projects, reaching the milestone about four years after its first export.

Venture Global Posts Strong Operating Profit GrowthIncome from operations climbed 110.8% year over year to $2.19 billion from $1.04 billion. Consolidated adjusted EBITDA increased 78.8% to $2.49 billion from $1.39 billion, with the EBITDA margin reaching 54%.

Net income attributable to common stockholders was $1.35 billion compared with $368 million a year earlier. Higher sales volumes and better LNG sales prices net of feed gas costs were the primary contributors to the EBITDA increase.

VG Sees Mixed Expense Trends in the QuarterCost of sales increased to $1.66 billion from $1.42 billion as LNG volumes rose. Operating and maintenance expenses advanced to $335 million from $217 million, reflecting increased commissioning work at Plaquemines and a larger fleet of Venture Global-owned ships in operation.

General and administrative expenses were $112 million compared with $103 million a year ago. Development expenses fell to $23 million from $57 million, while depreciation and amortization declined to $260 million from $267 million. Total operating expenses were $2.39 billion versus $2.06 billion.

Venture Global Advances Plaquemines & CP2Plaquemines remains in the final stages of construction, commissioning and assurance testing ahead of Phase 1 commercial operations. Venture Global continues to target Phase 1 commercial operations in the fourth quarter of 2026 and Phase 2 in mid-2027.

CP2 remains on schedule for first LNG in the second half of 2027. The project had 16 liquefaction modules on site, roofs raised on all four LNG storage tanks, and five gas and steam turbines on foundations. Engineering was 100% complete and procurement stood at 79%.

VG Raises Full-Year EBITDA GuidanceVenture Globalraised its 2026 consolidated adjusted EBITDA guidance to $8.70-$9.10 billion from $8.20-$8.50 billion. The updated range assumes a fixed liquefaction fee of $12.50-$13.50 per million British thermal units (MMBtu) for remaining unsold cargoes. A $1 per MMBtu change in the fee is expected to move full-year adjusted EBITDA by $180-$210 million.

The company expects 500-518 cargoes in 2026, including 149-154 from Calcasieu Pass and 351-364 from Plaquemines. As of Aug. 11, 91% of expected 2026 cargoes were contracted at a weighted-average liquefaction fee of $5.05 per MMBtu, while 75% of expected 2027 cargoes were contracted.

Venture Global Expands Liquidity & Shareholder ReturnsCash and restricted cash totaled $4.60 billion as of June 30, 2026, while total assets reached $61.52 billion. The company also had a $2-billion corporate revolving credit facility that remained undrawn and fully available.

Venture Global refinanced $5.30 billion of capital since the start of the second quarter, generating more than $100 million of expected annual interest and coupon savings. The board raised the quarterly dividend 122% to 4 cents per share, payable Sept. 30, to shareholders of record as of Sept. 15.

Zacks Rank & Key PicksVenture Global currently carries a Zacks Rank #3 (Hold).

Some better-ranked stocks from the energy sector are PBF Energy Inc. (PBF - Free Report) , HF Sinclair Corporation (DINO - Free Report) and Cactus, Inc. (WHD - Free Report) . PBF and DINO sport a Zacks Rank #1 (Strong Buy) at present, and WHD carries a Zacks Rank #2 (Buy). You can see the complete list of today’s Zacks Rank #1 stocks here.

PBF reported second-quarter 2026 adjusted earnings of $6.22 per share, surpassing the Zacks Consensus Estimate of $4.05.

As of June 30, 2026, PBF had total debt of $1.75 billion, and cash and cash equivalents of $894.1 million.

HF Sinclair reported second-quarter 2026 adjusted earnings of $5.31 per share, topping the Zacks Consensus Estimate of $4.39.

As of June 30, 2026, DINO had total debt of $2.77 billion, and cash and cash equivalents of $2.26 billion.

Cactus reported second-quarter 2026 adjusted earnings of 93 cents per share, surpassing the Zacks Consensus Estimate of 71 cents.

As of June 30, 2026, WHD had cash and cash equivalents of $365 million.

Tuesday, 11 August 2026 04:30 PM

Topic: 

Earnings HOUSTON, TX / ACCESS Newswire / August 11, 2026 / Stabilis Solutions, Inc., ("Stabilis" or the "Company") (Nasdaq:SLNG), a leading provider of clean fueling, production, storage, and last mile delivery solutions, today announced financial results for the second quarter ended June 30, 2026.

SECOND QUARTER 2026 HIGHLIGHTS

Revenues of $11.9 million; Net loss of ($4.6) million; Adjusted EBITDA of $0.1 million

71% year-over-year revenue growth from aerospace customers

Cash flow from operations of $7.1 million, including $5.0 million of advance payments from customers

$18.9 million of total available liquidity as of June 30, 2026

Executed a new contract for behind-the-meter LNG power generation at an additional U.S. data center, with service expected to commence in Q3 2026; the Company expects this contract will contribute to improved financial performance during the second half of 2026

Significant capital investment and pre-commissioning work underway for previously announced behind-the-meter LNG power generation at a U.S. data center, commencing Q1 2027

MANAGEMENT COMMENTARY

"Momentum is building across our business as we prepare for the early-2027 launch of our largest customer contract to date, a multi-year agreement to supply LNG for behind-the-meter power generation at a U.S. data center," stated Casey Crenshaw, Executive Chairman and Interim President & Chief Executive Officer. "Our second-quarter results were in line with our expectations, and demand recovered from the first-quarter low, led by 71% year-over-year growth in revenues from aerospace customers."

"We also made strong commercial progress during the quarter, including securing a six-month LNG supply agreement for commissioning of an additional U.S. data center, with service expected to begin in the third quarter of 2026," continued Crenshaw. "Together with continued demand growth in aerospace, this contract gives us visibility to improving financial performance through the balance of 2026, with second-half revenues expected to increase by over 50% compared to the first half of the year. As we prepare for the launch of our multi-year data center contract in early 2027, we are also pursuing additional opportunities to supply LNG for data center power generation. On the marine side, we made progress on our longer-term Gulf Coast strategy, receiving a U.S. Coast Guard Letter of Recommendation on the Waterway Suitability Assessment for our proposed Galveston LNG facility, which remains in development. We believe this will be the fastest to market, lowest cost per gallon dedicated LNG bunkering facility on the Gulf Coast.

"We view 2026 as a transition year, with the business having troughed in the first quarter and building through the second half, setting the stage for sustainable growth in 2027. Looking ahead, we are well positioned to capitalize on growing demand across our key end-markets, and we expect 2027 to be a record year for Stabilis, with revenues expected to ramp to well over $100 million for the full year," concluded Crenshaw.

FINANCIAL PERFORMANCE SUMMARY

Revenue for the second quarter of 2026 was $11.9 million, a decrease of 31.2% compared to the second quarter of 2025. The decrease in revenue compared to the prior year period was primarily attributable to the completion of large contracts in the marine and power generation sectors in Q4 of 2025, partly offset by continued growth in aerospace and industrial sector volumes.

Net loss for the second quarter of 2026 was ($4.6) million, or ($0.25) per diluted share, compared to a loss of ($0.6) million or ($0.03) per diluted share, in the second quarter of 2025. When compared to the prior year period, net loss reflects lower revenues and $2.9 million in vessel charter expenses associated with a marine vessel charter that was terminated late in the second quarter, partly offset by a $0.6 million decrease in selling, general and administrative expenses. The charter had been entered into in anticipation of a customer commitment that did not materialize, and was terminated accordingly. With the charter now terminated, the Company does not expect any further impact to earnings from this vessel charter beyond the second quarter.

Cash flow from operations was $7.1 million for the second quarter of 2026, compared to $4.5 million in the second quarter of last year, primarily reflecting $5.0 million in advance payments from a customer associated with a contract expected to begin in early 2027. Adjusted EBITDA (a non-GAAP financial measure) for the second quarter of 2026 was $0.1 million, compared to $1.5 million, in the year ago quarter. The decrease in Adjusted EBITDA year-over-year is primarily attributable to the completion of the two large multi-year contracts during the fourth quarter of 2025.

SECOND QUARTER 2026 CONFERENCE CALL AND WEBCAST

Stabilis will host a conference call on Wednesday August 12, 2026, at 9:00 a.m. ET to review the Company's financial results and conduct a question-and-answer session.

A webcast of the conference call will be available in the Investor Relations section of the Company's corporate website at https://investors.stabilis-solutions.com/events. To listen to a live broadcast, go to the site at least 15 minutes prior to the scheduled start time in order to register, download, and install any necessary audio software.

To participate in the live teleconference:

Domestic Live: 800-579-2543

International Live: 785-424-1789

Conference ID: SLNGQ226

To listen to a replay of the teleconference, which will be available through August 19, 2026:

Domestic Live: 800-839-6798

International Live: 402-220-6055

ABOUT STABILIS SOLUTIONS

Stabilis Solutions is a leading provider of clean fueling, production, storage, and last mile delivery solutions to multiple end markets. To learn more, visit www.stabilis-solutions.com.

CAUTIONARY STATEMENTS REGARDING FORWARD-LOOKING STATEMENTS

This press release includes "forward-looking statements" within the meaning of the safe harbor provisions of the U.S. Private Securities Litigation Reform Act of 1995 and within the meaning of Section 27a of the Securities Act of 1933, as amended, and Section 21e of the Securities Exchange Act of 1934, as amended. Any actual results may differ from expectations, estimates and projections presented or implied and, consequently, you should not rely on these forward-looking statements as predictions of future events. Words such as "can," "believes," "feels," "anticipates," "expects," "could," "will," "plan," "may," "should," "predicts," "potential", "outlook" and similar expressions are intended to identify such forward-looking statements.

Such forward-looking statements relate to future events or future performance, but reflect our current beliefs, based on information currently available. Most of these factors are outside our control and are difficult to predict. A number of factors could cause actual events, performance or results to differ materially from the events, performance and results discussed in the forward-looking statements. Factors that may cause such differences include, among other things: the future performance of Stabilis, future demand for and price of LNG, availability and price of natural gas, unexpected costs, availability, timing and terms of financing, ability to achieve the conditions precedent to the marine bunkering and other agreements, ability to achieve additional offtake necessary for FID for the planned LNG liquefaction facility and other commercial contracts, construction delays or cost overruns, regulatory or other legal impediments, and general economic conditions.

The foregoing list of factors is not exclusive. Additional information concerning these and other risk factors is contained in the Risk Factors in Item 1A of our Annual Report on Form 10-K filed with the Securities and Exchange Commission on March 5, 2026 which is available on the SEC's website at www.sec.gov or on the Investors section of our website at www.stabilis-solutions.com. All subsequent written and oral forward-looking statements concerning Stabilis, or other matters attributable to Stabilis, or any person acting on its behalf are expressly qualified in their entirety by the cautionary statements above. Readers are cautioned not to place undue reliance upon any forward-looking statements, which speak only as of the date made. Stabilis does not undertake or accept any obligation or undertaking to release publicly any updates or revisions to any forward-looking statement to reflect any change in their expectations or any change in events, conditions or circumstances on which any such statement is based, except as required by law.

Stabilis Solutions, Inc. and Subsidiaries
Selected Consolidated Operating Results
(Unaudited, in thousands, except share and per share data)

Three Months Ended

Six Months Ended

June 30,

March 31,

June 30,

June 30,

June 30,

2026

2026

2025

2026

2025

Revenues:

Revenues

$

11,916

$

10,379

$

17,309

$

22,295

$

34,647

Operating expenses:

Cost of revenues

9,569

8,521

12,724

18,090

25,512

Time charter expense

2,851

1,491

-

4,342

-

Change in unrealized (gain) loss on natural gas derivatives

-

-

60

-

(24

)

Selling, general and administrative expenses

2,501

2,796

3,131

5,297

8,064

Gain from disposal of fixed assets

-

-

-

-

(103

)

Impairment

-

71

-

71

-

Depreciation expense

1,777

1,785

1,860

3,562

3,727

Total operating expenses

16,698

14,664

17,775

31,362

37,176

Loss from operations before equity income

(4,782

)

(4,285

)

(466

)

(9,067

)

(2,529

)

Net equity income from foreign joint venture operations

215

227

50

442

418

Loss from operations

(4,567

)

(4,058

)

(416

)

(8,625

)

(2,111

)

Other income (expense):

Interest income, net

116

25

24

141

45

Other expense, net

(37

)

(37

)

(24

)

(74

)

(36

)

Total other income (expense)

79

(12

)

-

67

9

Net loss before income tax expense

(4,488

)

(4,070

)

(416

)

(8,558

)

(2,102

)

Income tax expense

149

6

197

155

109

Net loss

$

(4,637

)

$

(4,076

)

$

(613

)

$

(8,713

)

$

(2,211

)

Net loss per common share:

Basic and diluted per common share

$

(0.25

)

$

(0.22

)

$

(0.03

)

$

(0.47

)

$

(0.12

)

EBITDA

$

(2,827

)

$

(2,310

)

$

1,420

$

(5,137

)

$

1,580

Adjusted EBITDA

$

98

$

(672

)

$

1,480

$

(574

)

$

3,549

Stabilis Solutions, Inc. and Subsidiaries
Condensed Consolidated Balance Sheets
(Unaudited, in thousands, except share and per share data)

June 30,

December 31,

2026

2025

Assets

Current assets:

Cash and cash equivalents

$

4,535

$

7,459

Restricted cash and cash equivalents

14,317

-

Accounts receivable, net

3,360

3,130

Inventories, net

360

342

Prepaid expenses and other current assets

1,344

1,976

Total current assets

23,916

12,907

Property, plant and equipment:

Cost

133,751

125,613

Less accumulated depreciation

(75,270

)

(72,666

)

Property, plant and equipment, net

58,481

52,947

Goodwill

4,314

4,314

Investments in foreign joint ventures

11,528

11,946

Right-of-use assets and other noncurrent assets

1,113

996

Total assets

$

99,352

$

83,110

Liabilities and Stockholders' Equity

Current liabilities:

Accounts payable

$

9,081

$

4,750

Accrued liabilities

3,611

2,858

Current portion of long-term notes payable

1,418

1,931

Deferred revenue, current

680

1

Current portion of finance and operating lease obligations

221

417

Total current liabilities

15,011

9,957

Long-term notes payable, net of current portion and debt issuance costs

6,064

5,755

Deferred revenue, noncurrent

19,320

-

Long-term portion of operating lease obligations

521

726

Total liabilities

40,916

16,438

Commitments and contingencies

Stockholders' equity:

Common stock; $0.001 par value, 37,500,000 shares authorized, 18,596,301 and 18,596,301 shares issued and outstanding at June 30, 2026 and December 31, 2025, respectively

19

19

Additional paid-in capital

103,644

103,644

Accumulated other comprehensive income

487

10

Accumulated deficit

(45,714

)

(37,001

)

Total stockholders' equity

58,436

66,672

Total liabilities and stockholders' equity

$

99,352

$

83,110

Stabilis Solutions, Inc. and Subsidiaries
Condensed Consolidated Statements of Cash Flows
(Unaudited, in thousands)

Three Months Ended

Six Months Ended

June 30,

March 31,

June 30,

June 30,

June 30,

2026

2026

2025

2026

2025

Cash flows from operating activities:

Net loss

$

(4,637

)

$

(4,076

)

$

(613

)

$

(8,713

)

$

(2,211

)

Adjustments to reconcile net loss to net cash provided by operating activities:

Depreciation

1,777

1,785

1,860

3,562

3,727

Stock-based compensation expense

-

-

-

-

447

Provision for credit losses

-

-

106

-

113

Gain on disposal of assets

-

-

-

-

(103

)

Income from equity investment in joint venture

(258

)

(267

)

(120

)

(525

)

(537

)

Distributions from equity investment in joint venture

1,406

-

1,637

1,406

1,637

Impairment

-

71

-

71

-

Non-cash time charter cancellation

572

-

-

572

-

Amortization of debt issuance cost

27

27

-

54

48

Cash settlements from natural gas derivatives, net

-

-

76

-

239

Realized and unrealized gains on natural gas derivatives, net

-

-

225

-

141

Changes in operating assets and liabilities:

Accounts receivable

618

(848

)

205

(230

)

1,745

Prepaid expenses and other current assets

215

458

213

673

636

Accounts payable and accrued liabilities

2,810

398

898

3,208

(331

)

Deferred revenue

5,000

15,000

-

20,000

-

Other

(461

)

(131

)

28

(592

)

(11

)

Net cash provided by operating activities

7,069

12,417

4,515

19,486

5,540

Cash flows from investing activities:

Acquisition of fixed assets

(2,293

)

(5,268

)

(635

)

(7,561

)

(1,122

)

Proceeds from sale of fixed assets

-

-

-

-

211

Net cash used in investing activities

(2,293

)

(5,268

)

(635

)

(7,561

)

(911

)

Cash flows from financing activities:

Proceeds received from borrowings on notes payable

1,000

-

-

1,000

-

Payments on short- and long-term notes payable and finance leases

(630

)

(805

)

(680

)

(1,435

)

(1,351

)

Payment of debt issuance costs

(15

)

(84

)

-

(99

)

(42

)

Employee tax payments from stock-based withholding

-

-

-

-

(17

)

Net cash used in financing activities

355

(889

)

(680

)

(534

)

(1,410

)

Effect of exchange rate changes on cash

3

(1

)

17

2

14

Net increase in cash, cash equivalents and restricted cash and cash equivalents

5,134

6,259

3,217

11,393

3,233

Cash, cash equivalents and restricted cash and cash equivalents, beginning of period

13,718

7,459

9,003

7,459

8,987

Cash, cash equivalents and restricted cash and cash equivalents, end of period

$

18,852

$

13,718

$

12,220

$

18,852

$

12,220

Non-GAAP Measures

Our management uses EBITDA and Adjusted EBITDA to assess the performance and operating results of our business. EBITDA is defined as Earnings before Interest (includes interest income and interest expense), Taxes, Depreciation and Amortization. Adjusted EBITDA is defined as EBITDA further adjusted for certain special items that occur during the reporting period, as noted below. We include EBITDA and Adjusted EBITDA to provide investors with a supplemental measure of our operating performance. Neither EBITDA nor Adjusted EBITDA is a recognized term under generally accepted accounting principles in the U.S. ("GAAP"). Accordingly, they should not be used as an indicator of, or an alternative to, net income (loss) as a measure of operating performance. In addition, EBITDA and Adjusted EBITDA are not intended to be measures of free cash flow available for management's discretionary use, as they do not consider certain cash requirements, such as debt service requirements. Because the definition of EBITDA and Adjusted EBITDA may vary among companies and industries, it may not be comparable to other similarly titled measures used by other companies. The following table provides a reconciliation of net income (loss), the most directly comparable GAAP measure, to EBITDA and Adjusted EBITDA (in thousands).

Three Months Ended

Six Months Ended

June 30,

March 31,

June 30,

June 30,

June 30,

2026

2026

2025

2026

2025

Net loss

$

(4,637

)

$

(4,076

)

$

(613

)

$

(8,713

)

$

(2,211

)

Depreciation

1,777

1,785

1,860

3,562

3,727

Interest income, net

(116

)

(25

)

(24

)

(141

)

(45

)

Income tax expense

149

6

197

155

109

EBITDA

(2,827

)

(2,310

)

1,420

(5,137

)

1,580

Extraordinary vessel time charter costs, net

2,851

1,491

-

4,342

-

Impairment and other

74

147

-

221

-

Executive severance costs

-

-

-

-

2,096

Gain on disposal of fixed assets or settlement

-

-

-

-

(103

)

Change in unrealized loss (gain) on natural gas derivatives

-

-

60

-

(24

)

Adjusted EBITDA

$

98

$

(672

)

$

1,480

$

(574

)

$

3,549

# # # # #

Investor Contact:

Andrew Puhala
Chief Financial Officer
832-456-6502
[email protected]

SOURCE: Stabilis Solutions

3 Energy Stocks to Watch Now as LNG Demand SurgesCheniere Energy NYSE: LNG raised its 2026 financial outlook for a second consecutive quarter, citing higher production, stronger marketing margins and optimization activity as global LNG markets faced supply disruption tied to constrained flows through the Strait of Hormuz.

The company reported second-quarter consolidated adjusted EBITDA of approximately $1.8 billion, distributable cash flow of about $1.2 billion and net income of more than $3 billion. Cheniere produced and exported 184 cargoes totaling 672 TBtu during the quarter, a 20% increase from the prior-year period.

Get Cheniere Energy alerts:

3 LNG Stocks to Watch as Iran War ContinuesChairman, President and CEO Jack Fusco said operating performance benefited from the accelerated startup of additional Corpus Christi Stage 3 trains and improved reliability across the company’s facilities. Cheniere increased its full-year adjusted EBITDA forecast to a range of $7.9 billion to $8.4 billion and distributable cash flow guidance to $5.3 billion to $5.8 billion. The new low ends of both ranges exceed the prior high ends, Fusco said.

Production outlook rises as new capacity ramps Cheniere tightened its 2026 production guidance to 53 million to 54 million tons, compared with its prior range of 52 million to 54 million tons. CFO Zach Davis said only about one-third of the increase from the company’s original production outlook reflects Corpus Christi Stage 3 ramp-up, while more than two-thirds stems from reliability improvements, lower downtime and reduced maintenance requirements.

3 Stocks Sending a Strong Signal With Massive BuybacksDavis said the company’s updated guidance includes roughly $300 million from an additional 500,000 tons of expected production, based on margins of approximately $10 to $13. About $200 million of the increase was associated with higher margins and forward sales activity, while optimization contributed roughly $100 million to $150 million, he said.

Cheniere expects to have less than 1 million tons, or 50 TBtu, of unsold open volumes remaining in 2026. Davis said a $1 change in market margins is expected to affect full-year EBITDA by less than $50 million due to the limited remaining exposure.

Corpus Christi Stage 3 is more than 98% complete, according to Fusco. Train 6 reached substantial completion in June, while Train 7 entered commissioning and was expected to produce first LNG imminently. Cheniere expects Train 7 to reach substantial completion in the coming months, ahead of its guaranteed 2027 completion date.

The company’s mid-scale Trains 8 and 9 and related debottlenecking project were more than 48% complete. Fusco said piling had been completed, underground piping work was progressing, and key equipment packages, including the Train 8 cold box, were arriving at the site on or ahead of schedule.

Sabine Pass expansion advances toward FID During the quarter, Cheniere signed a lump-sum turnkey engineering, procurement and construction contract with Bechtel Energy for Phase I of its Sabine Pass expansion. The approximately $4.7 billion EPC contract covers one large-scale train, Sabine Pass Train 7, a boil-off gas reliquefaction unit and associated infrastructure and facility tie-ins.

Train 7 is designed for approximately 5 million tons per annum of capacity. The reliquefaction unit is expected to add about 1 million tons per annum across the Sabine Pass facility by debottlenecking existing large-scale trains. In total, Phase I is expected to add more than 6 million tons per annum, or roughly 10% growth in Cheniere’s production platform.

Bechtel has begun early engineering and procurement work under a limited notice to proceed. Baker Hughes is slated to supply turbines and compressors and will also provide fleetwide gas-turbine upgrades at Sabine Pass under a multiyear services agreement.

Fusco said Cheniere expects regulatory approvals later in 2026 and has begun financing work, providing what he described as clear visibility toward a final investment decision. Davis said formal FID is expected early next year. The company intends to fund about half of the Phase I project cost with debt and the other half with equity cash flow, including through flexibility in the variable component of the Cheniere Partners distribution.

Global market disruption boosts focus on supply security Executive Vice President and Chief Commercial Officer Anatol Feygin said LNG markets during the quarter were shaped by the conflict involving Iran and restrictions on tanker traffic through the Strait of Hormuz. He said LNG exports through the waterway remained severely constrained even after a mid-June ceasefire announcement.

According to Feygin, outbound crude tanker movements recovered to about 25% of their pre-conflict average by quarter-end, while LNG transit recovery remained below 10%. He said reduced Qatari and UAE shipments represented approximately 18 million tons of lower LNG supply during the quarter, partially offset by increased production elsewhere.

Overall global LNG exports declined by about 3 million tons year over year in the quarter, Feygin said. U.S. shipments shifted toward Asia as Asian prices moved above European prices, with U.S. LNG exports to Asia reaching a quarterly record of approximately 11 million tons.

Europe ended the quarter with an estimated 11 billion cubic meter storage deficit compared with the prior year, equivalent to roughly 100 LNG cargoes, Feygin said. He said Cheniere now believes it could be difficult for Europe to reach even 70% inventory levels before winter, below the region’s 80% storage target.

Feygin said the supply disruption reinforced the value of reliable delivery, portfolio diversification and contract flexibility. He added that Cheniere was comfortable it could secure mid-single-digit millions of tons of additional offtake to support the first phase of a Corpus Christi expansion over the next 12 to 18 months, though he described the broader contracting environment as competitive.

Capital returns and accounting changes Cheniere repurchased approximately 2.2 million shares for $550 million during the second quarter, bringing first-half buybacks to roughly $1.1 billion for nearly 5 million shares. The company also declared a quarterly dividend of $0.555 per common share and reiterated its commitment to grow the dividend by at least 10% annually through the end of the decade.

The company deployed nearly $900 million of equity cash flow during the quarter toward growth investments, shareholder returns and balance-sheet management. It also issued $1 billion of 2036 notes and $750 million of 2056 notes at Cheniere Partners, using proceeds to redeem $1.5 billion of senior secured notes due in 2027 at Sabine Pass and to fund a portion of early work on the Sabine Pass expansion.

Davis also said Cheniere designated the normal purchases and normal sales accounting exception for approximately 75% of volumes associated with its long-term integrated production marketing agreements. The change, effective in mid-June, means those agreements will no longer be marked to fair value each period and is expected to reduce quarterly net-income volatility related to noncash derivative accounting adjustments.

About Cheniere Energy (NYSE:LNG)Cheniere Energy, Inc is a U.S.-based energy company that develops, owns and operates liquefied natural gas (LNG) infrastructure and markets LNG to global customers. The company's core activities include natural gas liquefaction, long‑term and short‑term LNG sales and marketing, and the associated midstream services required to move gas from production basins to international markets. Cheniere focuses on converting domestic natural gas into LNG for export, providing a bridge between North American supply and overseas demand.

Cheniere's principal operating assets are large-scale LNG export terminals located on the U.S.

This instant news alert was generated by narrative science technology and financial data from MarketBeat in order to provide readers with the fastest reporting and unbiased coverage. Please send any questions or comments about this story to [email protected].

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Key Takeaways Cheniere raised 2026 EBITDA guidance to $7.9B-$8.4B as output, margins and optimization improved.LNG tightened 2026 production guidance to 53M-54M tonnes as operational outperformance drove gains.Cheniere advanced Corpus Christi Stage 3 and signed a $4.7B EPC contract for Sabine Pass Phase 1. Cheniere Energy, Inc. (LNG - Free Report) used its second-quarter 2026 earnings call to emphasize higher production, stronger marketing margins and operational execution, supporting a second consecutive increase to full-year 2026 guidance.

Management also highlighted energy-security concerns, progress on Corpus Christi Stage 3 and visibility into the next Sabine Pass expansion.

LNG Raises 2026 Guidance on Higher OutputChairman, president and CEO Jack Fusco said Cheniere raised full-year consolidated adjusted EBITDA guidance to $7.9 billion-$8.4 billion and distributable cash flow guidance to $5.3 billion-$5.8 billion. Both new low ends exceed the prior high ends.

CFO Zach Davis said the increase reflects higher production, spot-sale margins and optimization. Cheniere also tightened its 2026 production forecast to 53 million-54 million tonnes from 52 million-54 million tonnes.

LNG reported second-quarter 2026 earnings per share of $3.02, which topped the Zacks Consensus Estimate of $2.89. Second-quarter revenues of $5.73 billion also beat the Zacks Consensus Estimate of $5.03 billion by 14.00%.

Cheniere Extends Corpus Christi ExecutionCEO Jack Fusco said Corpus Christi Stage 3 was more than 98% complete, with Midscale Train 6 reaching substantial completion in June and first LNG from Train 7 expected imminently.

CEO Fusco added that Train 7 remains on track for substantial completion in the coming months, ahead of its guaranteed 2027 date. Midscale Trains 8 and 9 were more than 48% complete.

A JPMorgan analyst asked whether higher output could persist. CEO Fusco cited debottlenecking, improved maintenance execution and reliability work, while CFO Davis said more than two-thirds of the production increase versus Cheniere's initial forecast came from operational outperformance.

LNG Sees Security of Supply Driving DemandChief Commercial Officer Anatol Feygin said the Middle East supply disruption reinforced security of supply as a strategic priority for LNG buyers. He described the market as resilient but tightly balanced.

Chief Commercial Officer Feygin said European storage remained below prior-year levels and expected Europe to struggle to reach its 80% storage target before winter. He also said China's ability to offset tightness through lower LNG imports was approaching its limit.

A Barclays analyst asked about contracting momentum. Chief Commercial Officer Feygin said Cheniere remained comfortable securing the mid-single-digit millions of tonnes needed over the next 12 to 18 months to support Phase 1 of the Corpus Christi expansion.

Cheniere Moves Sabine Pass Expansion ForwardCEO Fusco said Cheniere signed a roughly $4.7 billion lump-sum turnkey EPC contract with Bechtel for Phase 1 of the Sabine Pass expansion and authorized early engineering and procurement.

The first phase includes Train 7, a boil-off gas reliquefaction unit and related infrastructure. CEO Fusco said it is expected to add more than 6 mtpa of production capacity.

CFO Davis said the project is fully commercialized and financing is underway, with formal final investment decision expected early next year. He said the expansion fits Cheniere's brownfield, contracted and returns-focused development model.

LNG Q&A Tests Upside From Margins and OptimizationA Wolfe Research analyst pressed management on the guidance increase. CFO Davis said roughly $300 million came from adding 0.5 million tonnes to the production forecast, about $200 million from stronger margins and Henry Hub effects, and $100 million-$150 million from optimization.

CFO Davis said Cheniere had less than 1 million tonnes, or 50 TBtu, of unsold 2026 volumes remaining. The company was also locking in additional volumes for 2027.

A BofA Securities analyst asked about accounting volatility. CFO Davis said a new designation covering about 75% of IPM agreement volumes should reduce future mark-to-market swings in quarterly net income.

Cheniere Maintains Capital Allocation DisciplineCFO Davis said Cheniere repurchased about 2.2 million shares for $550 million during Q2 and returned more than $1.3 billion to shareholders through buybacks and dividends in the first half.

CFO Davis also reiterated the goal of growing the dividend by at least 10% annually through the end of the decade while funding expansion and preserving investment-grade credit metrics.

Management's posture remained focused on operational reliability, disciplined brownfield growth and flexibility across shareholder returns, debt management and project investment.

LNG's Zacks Signals Point to a Balanced Style ProfileLNG carries a Zacks Rank #3 (Hold). Its Value, Growth and Momentum Scores are all C, while the VGM Score is B. You can see the complete list of today’s Zacks #1 Rank (Strong Buy) stocks here.

Within the Zacks framework, A or B Style Scores are most effective when paired with Zacks Rank #1 or 2 (Buy) stocks. LNG's B VGM Score is favorable, but its Zacks Rank #3 indicates a more neutral near-term earnings-revision signal. The Zacks Rank can change as estimates are revised after the latest results.

Not for distribution to United States newswire services or for dissemination in the United States

TORONTO, ON / ACCESS Newswire / August 6, 2026 / LNG Energy Group Corp. (TSXV:LNGE)(TSXV:LNGE.WT)(OTC PINK:LNGNF)(FWB:E26) (the "Company" or "LNG Energy Group") announces that the Ontario Securities Commission (the "OSC") has issued a second partial revocation order on August 6, 2026 (the "Second Order"), partially revoking the failure-to-file cease trade order issued against the Company on May 7, 2025 (the "FFCTO") for failing to file certain outstanding continuous disclosure documents. The Second Order replaces the first partial revocation order previously issued by the OSC on April 23, 2026, which was deemed to be terminated on July 22, 2026 (the "First Order"). The Second Order permits the Company to continue its previously announced private placement financing (the "Private Placement"), as announced on May 1, 2026, for the purposes of: (i) filing its outstanding continuous disclosure documents, (ii) paying accounting, audit and legal fees associated with the preparation and filing of the relevant continuous disclosure documents, (iii) paying costs and fees associated with the Private Placement, (iv) paying legacy accounts payable, (iv) paying filing fees, including for the application for a full revocation of the FFCTO, and (v) funding working capital and general and administrative expenses until a full revocation of the FFCTO is obtained.

The Second Order of the FFCTO was pursued to permit the Company to continue its Private Placement of units of the Company ("Units") for aggregate gross proceeds of up to $2,000,000. Each Unit will continue to be priced at $0.05 and will comprise one common share of the Company (each, a "Common Share") and one Common Share purchase warrant (each, a "Warrant") with each Warrant being exercisable to acquire one Common Share at a price of $0.10 per share for a period of 36 months following the closing date of the Private Placement. The Private Placement will be conducted on a prospectus exempt basis with investors: (i) resident in Canada in reliance on, and in accordance with, the accredited investor exemption in section 73.3 of the Securities Act (Ontario) or section 2.3 of National Instrument 45-106 - Prospectus Exemptions ("NI 45-106"), as applicable; (ii) in the United States pursuant to available exemptions from United States registration requirements and in accordance with OSC Rule 72-503 - Distributions Outside Canada; and (iii) in such offshore jurisdictions pursuant to available prospectus or registration exemptions in accordance with applicable laws. The Company also intends to issue Units to certain arm's length creditors in settlement of bona fide debts in reliance upon the securities for debt exemption contained in section 2.14 of NI 45-106.

Prior to completion of the Private Placement, each participant will receive a copy of the FFCTO, the First Order and the Second Order, and will be required to provide an acknowledgement to the Company that all of the Company's securities, including the securities issued in connection with the Private Placement, will remain subject to the FFCTO until such order is fully revoked, and that the granting of a partial revocation of the FFCTO does not guarantee the issuance of a full revocation order in the future. In addition, all securities issued pursuant to the Private Placement will be subject to a hold period of four months and a day from the closing date of the Private Placement.

The Second Order will terminate on the earlier of: (i) the completion of the Private Placement, and (ii) November 4, 2026, being 90 days from the date on which the Second Order was issued. There can be no assurances that the Private Placement will be completed on the terms set out herein, or at all, or that the proceeds of the Private Placement will be sufficient for the purposes of the Company. The Company will also issue appropriate press releases and file material change reports on SEDAR+, as applicable, upon completion of the Private Placement.

The securities being referred to in this news release have not been, nor will they be, registered under the United States (U.S.) Securities Act of 1933, as amended, and may not be offered or sold in the U.S. or to, or for the account or benefit of, U.S. persons absent registration or an applicable exemption from the registration requirements. This news release does not constitute an offer to sell or the solicitation of an offer to buy nor shall there be any sale of the securities in any jurisdiction in which such offer, solicitation or sale would be unlawful.

About LNG Energy Group

The Company is focused on the acquisition and development of natural gas production and exploration assets in Latin America. For more information, please visit www.lngenergygroup.com.

For more information please contact:

Angel Roa, Chief Financial Officer LNG Energy Group Corp.
Website: www.lngenergygroup.com
Email: [email protected]

Find us on social media:

LinkedIn: https://www.linkedin.com/company/lng-energy-group-inc/
Instagram: @lngenergygroup
X: @LNGEnergyCorp

CAUTIONARY NOTE REGARDING FORWARD-LOOKING INFORMATION:

This news release contains "forward-looking information" and "forward-looking statements" (collectively, "forward-looking statements") within the meaning of applicable Canadian securities laws. All statements other than statements of historical fact are forward-looking statements, and are based on expectations, estimates and projections as at the date of this news release that reflect the current views and/or expectations of management of LNG Energy Group with respect to performance, business and future events. Forward-looking information can often be identified by words such as "may", "will", "would", "could", "should", "believes", "estimates", "projects", "potential", "expects", "plans", "intends", "anticipates", "targeted", "continues", "forecasts", "designed", "goal", or the negative of those words or other similar or comparable words. Forward-looking statements are based on the then-current expectations, beliefs, assumptions, estimates and forecasts about the business and the industry and markets in which LNG Energy Group operates, in light of our experience and perception of historical trends, current conditions and expected future developments, as well as other factors that we believe are appropriate and reasonable in the circumstances, and that while considered reasonable, are subject to known and unknown risks, uncertainties and other factors that may cause actual results to differ materially from those expressed or implied in the forward-looking information. There can be no assurance that such statements will prove to be accurate, and accordingly, readers should not place undue reliance on the forward-looking statements contained in this news release. LNG Energy Group does not undertake any obligation to release publicly any revisions or updating any voluntary forward-looking statements, except as required by applicable securities law, whether they change as a result of new information, future events or otherwise.

This news release includes, but is not limited to, forward-looking statements relating to: the timing, terms and completion of the Private Placement, the use of funds from the Private Placement, the Company preparing and filing all outstanding continuous disclosure documents, and the Company applying for and receiving full revocation of the FFCTO. Forward-looking statements in this press release are based on certain assumptions, namely: the ability of the Company to continue as a going concern, the ability of the Company to complete the Private Placement, the ability of the Company to use the funds from the Private Placement as intended, the ability of the Company to prepare and file all outstanding continuous disclosure documents and the Company's ability to apply for and receive full revocation of the FFCTO. Forward-looking statements address future events and conditions and therefore involve inherent risks and uncertainties, including, but not limited to: the inability of the Company to complete the Private Placement, the inability of the Company to obtain approval from the TSX Venture Exchange, the inability of the Company to use the funds from the Private Placement for the intended purposes, the inability of the Company to prepare and file all outstanding continuous disclosure documents and the inability of the Company to have the FFCTO fully revoked. The Company's actual decisions, activities, results, performance, or achievement could differ materially from those expressed in, or implied by, such forward- looking statements and accordingly, no assurances can be given that any of the events anticipated by the forward- looking statements will transpire or occur or, if any of them do, what benefits that the Company will derive from them.

Neither the TSX Venture Exchange nor its Regulation Services Provider (as that term is defined in the policies of the TSX Venture Exchange) accepts responsibility for the adequacy or accuracy of this release.

SOURCE: LNG Energy Group Corp.

Cheniere Energy (LNG - Free Report) came out with quarterly earnings of $3.02 per share, beating the Zacks Consensus Estimate of $2.89 per share. This compares to earnings of $7.3 per share a year ago. These figures are adjusted for non-recurring items.

This quarterly report represents an earnings surprise of +4.50%. A quarter ago, it was expected that this natural gas company would post earnings of $3.91 per share when it actually produced earnings of $4.77, delivering a surprise of +21.99%.

Over the last four quarters, the company has surpassed consensus EPS estimates three times.

Cheniere Energy, which belongs to the Zacks Oil and Gas - Exploration and Production - United States industry, posted revenues of $5.73 billion for the quarter ended June 2026, surpassing the Zacks Consensus Estimate by 13.96%. This compares to year-ago revenues of $4.64 billion. The company has topped consensus revenue estimates three times over the last four quarters.

The sustainability of the stock's immediate price movement based on the recently-released numbers and future earnings expectations will mostly depend on management's commentary on the earnings call.

Cheniere Energy shares have added about 31.1% since the beginning of the year versus the S&P 500's gain of 12.8%.

What's Next for Cheniere Energy?While Cheniere Energy has outperformed the market so far this year, the question that comes to investors' minds is: what's next for the stock?

There are no easy answers to this key question, but one reliable measure that can help investors address this is the company's earnings outlook. Not only does this include current consensus earnings expectations for the coming quarter(s), but also how these expectations have changed lately.

Empirical research shows a strong correlation between near-term stock movements and trends in earnings estimate revisions. Investors can track such revisions by themselves or rely on a tried-and-tested rating tool like the Zacks Rank, which has an impressive track record of harnessing the power of earnings estimate revisions.

Ahead of this earnings release, the estimate revisions trend for Cheniere Energy was mixed. While the magnitude and direction of estimate revisions could change following the company's just-released earnings report, the current status translates into a Zacks Rank #3 (Hold) for the stock. So, the shares are expected to perform in line with the market in the near future. You can see the complete list of today's Zacks #1 Rank (Strong Buy) stocks here.

It will be interesting to see how estimates for the coming quarters and the current fiscal year change in the days ahead. The current consensus EPS estimate is $3.36 on $5.37 billion in revenues for the coming quarter and -$2.60 on $21.67 billion in revenues for the current fiscal year.

Investors should be mindful of the fact that the outlook for the industry can have a material impact on the performance of the stock as well. In terms of the Zacks Industry Rank, Oil and Gas - Exploration and Production - United States is currently in the bottom 13% of the 250 plus Zacks industries. Our research shows that the top 50% of the Zacks-ranked industries outperform the bottom 50% by a factor of more than 2 to 1.

Another stock from the same industry, California Resources Corporation (CRC - Free Report) , has yet to report results for the quarter ended June 2026. The results are expected to be released on August 10.

This company is expected to post quarterly earnings of $1.31 per share in its upcoming report, which represents a year-over-year change of +19.1%. The consensus EPS estimate for the quarter has been revised 34.3% lower over the last 30 days to the current level.

California Resources Corporation's revenues are expected to be $979.33 million, up 0.1% from the year-ago quarter.

HOUSTON--(BUSINESS WIRE)--Cheniere Energy, Inc. (“Cheniere”) (NYSE: LNG) today announced its financial results for the second quarter 2026.

SECOND QUARTER 2026 SUMMARY FINANCIAL RESULTS

(in billions)

Three Months Ended June 30, 2026

Six Months Ended June 30, 2026

Revenues

$5.73

$11.60

Net Income (Loss)1,2

$3.07

($0.43)

Consolidated Adjusted EBITDA3

$1.80

$4.14

Distributable Cash Flow3

$1.17

$2.84

2026 FULL YEAR FINANCIAL GUIDANCE

(in billions)

2026 Previous

2026 Revised

Consolidated Adjusted EBITDA3

$7.25

-

$7.75

$7.90

-

$8.40

Distributable Cash Flow3

$4.75

-

$5.25

$5.30

-

$5.80

RECENT HIGHLIGHTS

Financial

During the three and six months ended June 30, 2026, Cheniere generated revenues of approximately $5.7 billion and $11.6 billion, Consolidated Adjusted EBITDA3 of approximately $1.8 billion and $4.1 billion, Distributable Cash Flow3 of approximately $1.2 billion and $2.8 billion, and net income (loss)1,2 of approximately $3.1 billion and ($434) million, respectively. For the twelve months ended June 30, 2026, Cheniere generated net income of approximately $2.9 billion. Raising full year 2026 Consolidated Adjusted EBITDA3 guidance from $7.25 billion - $7.75 billion to $7.90 billion - $8.40 billion and full year 2026 Distributable Cash Flow3 guidance from $4.75 billion - $5.25 billion to $5.30 billion - $5.80 billion. Capital Allocation

During the three and six months ended June 30, 2026, Cheniere deployed approximately $884 million and $2.1 billion, respectively, under its comprehensive capital allocation plan by: Repurchasing an aggregate of approximately 2.2 million and 4.9 million shares of common stock for approximately $550 million and $1.1 billion, respectively, Paying quarterly dividends of $0.555 and $1.110 per share of common stock, totaling approximately $116 million and $233 million, respectively, Investing approximately $1.1 billion and $2.1 billion of growth capital with approximately $219 million and $520 million funded with equity, respectively, and Repaying approximately $253 million of consolidated long-term indebtedness in the six months ended June 30, 2026 In July 2026, Cheniere declared a dividend with respect to the second quarter 2026 of $0.555 per share of common stock, which is payable on August 18, 2026. Growth / Operations

During the three and six months ended June 30, 2026, a total of 184 and 371 cargoes of liquefied natural gas (“LNG”) were exported from our facilities, respectively. Tightening the full year 2026 production forecast range upward to 53-54 million tonnes from 52-54 million tonnes. In June 2026, substantial completion of the sixth train (“Midscale Train 6”) of the CCL Stage 3 Project (defined below) was achieved. This follows the previously announced substantial completions of Midscale Trains 1-4 of the CCL Stage 3 Project in 2025 and Midscale Train 5 of the CCL Stage 3 Project in March 2026. First LNG production from the seventh train (“Midscale Train 7”) of the CCL Stage 3 Project is expected imminently. In June 2026, we received authorization from the Federal Energy Regulatory Commission (“FERC”) to increase the LNG production capacity of the previously-authorized CCL Stage 3 Project and CCL Midscale Trains 8 & 9 Project (defined below) by approximately 5 million tonnes per annum (“mtpa”) in aggregate. In May 2026, Sabine Pass Liquefaction Stage V, LLC, a subsidiary of Cheniere Energy Partners, L.P. (“Cheniere Partners”) (NYSE: CQP) entered into a lump sum, turnkey, engineering, procurement and construction (“EPC”) contract with Bechtel Energy, Inc. (“Bechtel”) for the first phase of the SPL Expansion Project (defined below) and has released Bechtel to commence early engineering and procurement under a limited notice to proceed (“LNTP”). CEO COMMENT

“The second quarter of 2026 marked another outstanding quarter for Cheniere, highlighted by the substantial completion of Midscale Train 6 at the CCL Stage 3 Project, and our further progress towards an FID of Phase 1 of the SPL Expansion Project,” said Jack Fusco, Cheniere’s Chairman, President and Chief Executive Officer. “Our strong financial and operational results year-to-date, coupled with our constructive outlook and enhanced visibility for the remainder of the year, have enabled us to once again raise our full year 2026 Consolidated Adjusted EBITDA and Distributable Cash Flow guidance ranges. We look forward to delivering full year financial results within these further improved ranges.”

SUMMARY AND REVIEW OF FINANCIAL RESULTS

(in millions, except LNG data)

Three Months Ended June 30,

Six Months Ended June 30,

2026

2025

% Change

2026

2025

% Change

Revenues

$

5,732

$

4,641

24

%

$

11,600

$

10,085

15

%

Net income (loss)1,2

$

3,068

$

1,626

89

%

$

(434

)

$

1,979

N/M

Consolidated Adjusted EBITDA3

$

1,804

$

1,416

27

%

$

4,137

$

3,288

26

%

LNG exported:

Number of cargoes

184

154

19

%

371

322

15

%

Volumes (TBtu)

672

550

22

%

1,360

1,159

17

%

LNG volumes loaded (TBtu)

672

550

22

%

1,360

1,158

17

%

Net income (loss)1,2 was approximately $3.1 billion and $(434) million for the three and six months ended June 30, 2026, respectively, as compared to net income1,2 of approximately $1.6 billion and $2.0 billion for the corresponding 2025 periods. The changes for the three and six months ended June 30, 2026 are attributable to approximately $1.4 billion of favorable variances and $3.4 billion of unfavorable variances, respectively, related to changes in the fair value of our derivative instruments, predominantly related to our long-term Integrated Production Marketing (“IPM”) agreements (before tax and non-controlling interests), as well as higher total margins on LNG delivered, primarily driven by higher volumes recognized in income. The favorable change for the three months ended June 30, 2026 was partially offset by higher net income attributable to non-controlling interests relative to the 2025 period. The unfavorable change for the six months ended June 30, 2026 was partially offset by the recognition of a nonrecurring excise tax credit during the 2026 period and lower provisions for income tax relative to the 2025 period.

Share-based compensation expenses included in net income (loss) totaled $37 million and $115 million for the three and six months ended June 30, 2026, respectively, compared to $49 million and $105 million for the corresponding 2025 periods.

Consolidated Adjusted EBITDA3 increased approximately $388 million and $849 million for the three and six months ended June 30, 2026, respectively, as compared to the corresponding 2025 periods, due to higher total margins on LNG delivered, primarily driven by higher volumes recognized in income, as well as higher margins per MMBtu of LNG delivered during the period.

Our financial results are reported on a consolidated basis. Our ownership interest in Cheniere Partners as of June 30, 2026 consisted of 100% ownership of the general partner interest and a 48.6% limited partner interest.

BALANCE SHEET MANAGEMENT

Capital Resources

The table below provides a summary of our available liquidity (in millions) as of June 30, 2026:

June 30, 2026

Cash and cash equivalents(1)

$

1,099

Restricted cash and cash equivalents(2)

420

Available commitments under our credit facilities:

Sabine Pass Liquefaction, LLC (“SPL”) Revolving Credit Facility

871

Cheniere Partners Revolving Credit Facility

1,000

Cheniere Corpus Christi Holdings, LLC (“CCH”) Credit Facility

1,510

CCH Revolving Credit Facility

825

Cheniere Revolving Credit Facility

1,750

Total available commitments under our credit facilities

5,956

Total available liquidity

$

7,475

Recent Key Financial Transactions and Updates

In June 2026, the Cheniere Revolving Credit Facility was amended to extend its maturity by one year and increase the aggregate commitments by $500 million to $1.75 billion, and the CCH Working Capital Facility, now the CCH Revolving Credit Facility, was amended and restated to, among other things, extend the maturity date by approximately four years, reduce the rates applicable to our interest and fees, and decrease aggregate commitments by $500 million to $1.0 billion.

In June 2026, the CCH Credit Facility was amended and restated to extend the availability period for disbursements to the later of the completion of the CCL Stage 3 Project and December 31, 2027. In May 2026, $600 million of unused commitments under the CCH Credit Facility were cancelled.

In June 2026, Cheniere Partners issued $1.0 billion aggregate principal amount of 5.350% Senior Notes due 2036 and $750 million aggregate principal amount of 6.050% Senior Notes due 2056, and a portion of the net proceeds were used to fully redeem $1.5 billion aggregate principal amount of SPL’s 5.00% Senior Secured Notes due 2027, as well as for general corporate purposes, including funding a portion of the LNTP related to the first phase of the SPL Expansion Project.

LIQUEFACTION PROJECTS OVERVIEW

In aggregate across the Sabine Pass LNG terminal and the Corpus Christi LNG terminal, we have approximately 55 mtpa of liquefaction capacity in operation, over 6 mtpa under construction, and over 40 mtpa in the regulatory permitting process.

SPL Project

Through Cheniere Partners, we operate liquefaction and export facilities with a total production capacity of over 30 mtpa of LNG at the Sabine Pass LNG terminal in Cameron Parish, Louisiana (the “SPL Project”).

SPL Expansion Project

Through Cheniere Partners, we are developing an expansion adjacent to the SPL Project with an expected total peak production capacity of up to approximately 20 mtpa of LNG (the “SPL Expansion Project”), inclusive of estimated debottlenecking opportunities. We expect to execute the SPL Expansion Project in a phased approach, and a positive Final Investment Decision (“FID”) is subject to, among other things, receipt of necessary regulatory approvals and acceptable commercial and financing arrangements. The FERC application for authorization to site, construct and operate the SPL Expansion Project, as well as the Department of Energy (“DOE”) application authorizing the export of LNG to non-free trade agreement (“FTA”) countries, remain pending. In May 2026, the lump sum, turnkey EPC contract with Bechtel for the first phase of the SPL Expansion Project was signed, and Bechtel was released to commence early engineering and procurement under a LNTP. The first phase includes a single train, Train 7, and a boil-off gas re-liquefaction unit, along with supporting infrastructure and tie-ins to the existing Sabine Pass LNG terminal, and has an expected total production capacity of over 6 mtpa of LNG, inclusive of estimated debottlenecking opportunities.

CCL Project

We operate liquefaction and export facilities with a total production capacity of over 24 mtpa of LNG at the Corpus Christi LNG terminal near Corpus Christi, Texas (the “CCL Project”), inclusive of Midscale Trains 1-6 of the CCL Stage 3 Project.

CCL Stage 3 Project

We are constructing an expansion of the CCL Project consisting of seven Midscale Trains with an expected total production capacity of over 10 mtpa of LNG (the “CCL Stage 3 Project”), including approximately 9 mtpa in operation and over 1 mtpa under construction. Substantial completion was achieved for Midscale Trains 1-4 of the CCL Stage 3 Project in 2025, and Midscale Trains 5 and 6 in March and June 2026, respectively. First LNG is expected imminently from Midscale Train 7, which is expected to reach substantial completion in the fall of 2026.

CCL Midscale Trains 8 & 9 Project

We are constructing an expansion adjacent to the CCL Stage 3 Project consisting of two additional Midscale Trains with an expected total production capacity of approximately 5 mtpa of LNG (the “CCL Midscale Trains 8 & 9 Project”), inclusive of estimated debottlenecking opportunities.

CCL Stage 3 Project and CCL Midscale Trains 8 & 9 Project Progress as of June 30, 2026:

CCL Stage 3 Project

CCL Midscale Trains 8 & 9 Project

Project Status

Trains 1-6 Operational

Train 7 Under Construction / Commissioning

Under Construction

Project Completion Percentage

98.4%(1)

48.3%(2)

Expected Substantial Completion

2H 2026

2H 2028

CCL Expansion Project

We are developing an expansion adjacent to the CCL Project with an expected total peak production capacity of up to approximately 24 mtpa of LNG, inclusive of estimated debottlenecking opportunities (the “CCL Expansion Project”). We expect to execute the CCL Expansion Project in a phased approach, and a positive FID is subject to, among other things, receipt of necessary regulatory approvals and acceptable commercial and financing arrangements. The FERC application for authorization to site, construct and operate the CCL Expansion Project, as well as the DOE application authorizing the export of LNG to non-FTA countries, remain pending.

INVESTOR CONFERENCE CALL AND WEBCAST

We will host a conference call to discuss our financial and operating results for the second quarter 2026 on Thursday, August 6, 2026, at 11 a.m. Eastern time / 10 a.m. Central time. A listen-only webcast of the call and an accompanying slide presentation may be accessed through our website at www.cheniere.com. Following the call, an archived recording will be made available on our website.

About Cheniere

Cheniere Energy, Inc. is the leading producer and exporter of LNG in the United States, reliably providing a clean, secure, and affordable solution to the growing global need for natural gas. Cheniere is a full-service LNG provider, with capabilities that include gas procurement and transportation, liquefaction, vessel chartering, and LNG delivery. Cheniere has one of the largest liquefaction platforms in the world, consisting of the Sabine Pass and Corpus Christi liquefaction facilities on the U.S. Gulf Coast, with a total combined production capacity of approximately 55 mtpa of LNG in operation and an additional over 6 mtpa of expected production capacity under construction or in commissioning, inclusive of estimated debottlenecking opportunities. Cheniere is also pursuing liquefaction expansion opportunities and other projects along the LNG value chain. Cheniere is headquartered in Houston, Texas, and has additional offices in London, Singapore, Beijing, Tokyo, Dubai and Washington, D.C.

For additional information, please refer to the Cheniere website at www.cheniere.com and Quarterly Report on Form 10-Q for the quarter ended June 30, 2026, filed with the Securities and Exchange Commission.

Use of Non-GAAP Financial Measures

In addition to disclosing financial results in accordance with U.S. GAAP, the accompanying news release contains non-GAAP financial measures. Consolidated Adjusted EBITDA and Distributable Cash Flow are non-GAAP financial measures that we use to facilitate comparisons of operating performance across periods. These non-GAAP measures should be viewed as a supplement to and not a substitute for our U.S. GAAP measures of performance and the financial results calculated in accordance with U.S. GAAP and reconciliations from these results should be carefully evaluated.

Non-GAAP measures have limitations as an analytical tool and should not be considered in isolation or in lieu of an analysis of our results as reported under GAAP and should be evaluated only on a supplementary basis.

Forward-Looking Statements

This press release contains certain statements that may include “forward-looking statements” within the meanings of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. All statements, other than statements of historical or present facts or conditions, included herein are “forward-looking statements.” Included among “forward-looking statements” are, among other things, (i) statements regarding Cheniere’s financial and operational guidance, business strategy, plans and objectives, including the development, construction and operation of liquefaction facilities, (ii) statements regarding regulatory authorization and approval expectations, (iii) statements expressing beliefs and expectations regarding the development of Cheniere’s LNG terminal and pipeline businesses, including liquefaction facilities, (iv) statements regarding the business operations and prospects of third-parties, (v) statements regarding potential financing arrangements, (vi) statements regarding future discussions and entry into contracts, (vii) statements relating to Cheniere’s capital deployment, including intent, ability, extent, and timing of capital expenditures, debt repayment, dividends, share repurchases and execution on the capital allocation plan, and (viii) statements relating to our goals, commitments and strategies in relation to environmental matters. Although Cheniere believes that the expectations reflected in these forward-looking statements are reasonable, they do involve assumptions, risks and uncertainties, and these expectations may prove to be incorrect. Cheniere’s actual results could differ materially from those anticipated in these forward-looking statements as a result of a variety of factors, including those discussed in Cheniere’s periodic reports that are filed with and available from the Securities and Exchange Commission. You should not place undue reliance on these forward-looking statements, which speak only as of the date of this press release. Other than as required under the securities laws, Cheniere does not assume a duty to update these forward-looking statements.

(Financial Tables and Supplementary Information Follow)

LNG VOLUME SUMMARY

As of July 31, 2026, over 4,940 cumulative LNG cargoes totaling over 340 million tonnes of LNG have been produced, loaded and exported from our liquefaction projects.

During the three and six months ended June 30, 2026, we exported 672 and 1,360 TBtu, respectively, of LNG from our liquefaction projects, 3 and 9 TBtu of which was related to commissioning activities, respectively. 72 TBtu of LNG exported from our liquefaction projects and sold on a delivered basis was in transit as of June 30, 2026, 1 TBtu of which was related to commissioning activities.

The following table summarizes the volumes of LNG that were loaded from our liquefaction projects and for which the financial impact was recognized on our Consolidated Financial Statements during the three and six months ended June 30, 2026:

  Three Months Ended June 30, 2026

Six Months Ended June 30, 2026

(in TBtu)

  Operational

Commissioning

Total

Operational

Commissioning

Total

Volumes loaded during the current period

  669

3

672

1,351

9

1,360

Volumes loaded during the prior period but recognized during the current period

  59

1

60

23

1

24

Less: volumes loaded during the current period and in transit at the end of the period

  (71

)

(1

)

(72

)

(71

)

(1

)

(72

)

Total volumes recognized in the current period

  657

3

660

1,303

9

1,312

In addition, during the six months ended June 30, 2026, we recognized 36 TBtu of LNG on our Consolidated Financial Statements related to LNG cargoes sourced from third-parties.

Cheniere Energy, Inc.

Consolidated Statements of Operations

(in millions, except per share data)(1)

(unaudited)

  Three Months Ended

Six Months Ended

June 30,

June 30,

2026

2025

2026

2025

Revenues

LNG revenues

$

5,640

$

4,515

$

11,362

$

9,820

Regasification revenues

34

34

68

68

Other revenues

58

92

170

197

Total revenues

5,732

4,641

11,600

10,085

Operating costs and expenses

Cost of sales (excluding operating and maintenance expense and depreciation, amortization and accretion expense shown separately below) (2)

439

1,117

8,757

4,688

Operating and maintenance expense

533

559

1,058

1,032

Selling, general and administrative expense

88

99

224

215

Depreciation, amortization and accretion expense

380

329

753

641

Other operating costs and expenses

2

7

6

18

Total operating costs and expenses

1,442

2,111

10,798

6,594

Income from operations

4,290

2,530

802

3,491

Other income (expense)

Interest expense, net of capitalized interest

(287

)

(237

)

(542

)

(466

)

Interest and dividend income

19

31

35

68

Other income (expense), net

(14

)

(1

)

(40

)

19

Total other expense

(282

)

(207

)

(547

)

(379

)

Income before income taxes and non-controlling interests

4,008

2,323

255

3,112

Less: income tax provision

366

426

25

547

Net income

3,642

1,897

230

2,565

Less: net income attributable to non-controlling interests

574

271

664

586

Net income (loss) attributable to Cheniere

$

3,068

$

1,626

$

(434

)

$

1,979

Net income (loss) per share attributable to common stockholders—basic (1)

$

14.68

$

7.32

$

(2.08

)

$

8.87

Net income (loss) per share attributable to common stockholders—diluted (1)

$

14.65

$

7.30

$

(2.08

)

$

8.85

Weighted average number of common shares outstanding—basic

209.0

221.8

209.7

222.6

Weighted average number of common shares outstanding—diluted

209.5

222.3

209.7

223.2

Cheniere Energy, Inc.

Consolidated Balance Sheets

(in millions, except share data)(1)(2)

(unaudited)

  June 30,

December 31,

2026

2025

ASSETS

Current assets

Cash and cash equivalents

$

1,099

$

1,099

Restricted cash and cash equivalents

420

485

Trade and other receivables, net of current expected credit losses

1,335

1,380

Inventory

723

524

Current derivative assets

156

9

Margin deposits

126

76

Prepaid expenses

117

72

Other current assets, net

136

47

Total current assets

4,112

3,692

Property, plant and equipment, net of accumulated depreciation

37,154

35,755

Operating lease assets

2,516

2,700

Deferred NPNS assets

2,195

—

Derivative assets

735

4,663

Other non-current assets, net

1,260

1,072

Total assets

$

47,972

$

47,882

LIABILITIES, REDEEMABLE NON-CONTROLLING INTEREST AND STOCKHOLDERS’ EQUITY

Current liabilities

Accounts payable

$

293

$

123

Accrued liabilities

1,676

2,081

Current debt, net of unamortized discount and debt issuance costs

1,411

306

Deferred revenue

116

150

Current operating lease liabilities

562

539

Current portion of deferred NPNS liabilities

166

—

Current derivative liabilities

377

618

Other current liabilities

122

99

Total current liabilities

4,723

3,916

Long-term debt, net of unamortized discount and debt issuance costs

22,632

22,507

Operating lease liabilities

1,951

2,163

Deferred NPNS liabilities

1,740

—

Derivative liabilities

301

1,208

Deferred tax liabilities

3,629

3,698

Other non-current liabilities

1,506

1,312

Total liabilities

36,482

34,804

Redeemable non-controlling interest

—

136

Stockholders’ equity

Preferred stock: $0.0001 par value, 5.0 million shares authorized, none issued

—

—

Common stock: $0.003 par value, 480.0 million shares authorized; 279.6 million shares and 279.2 million shares issued at June 30, 2026 and December 31, 2025, respectively

1

1

Treasury stock: 71.7 million shares and 66.8 million shares at June 30, 2026 and December 31, 2025, respectively, at cost

(9,949

)

(8,852

)

Additional paid-in-capital

4,566

4,523

Retained earnings

11,573

12,243

Total Cheniere stockholders’ equity

6,191

7,915

Non-controlling interests

5,299

5,027

Total stockholders’ equity

11,490

12,942

Total liabilities, redeemable non-controlling interest and stockholders’ equity

$

47,972

$

47,882

Reconciliation of Non-GAAP Measures
Regulation G Reconciliations

Consolidated Adjusted EBITDA

The following table reconciles our Consolidated Adjusted EBITDA to U.S. GAAP results for the three and six months ended June 30, 2026 and 2025 (in millions):

Three Months Ended June 30,

Six Months Ended June 30,

2026

2025

2026

2025

Net income (loss) attributable to Cheniere

$

3,068

$

1,626

$

(434

)

$

1,979

Net income attributable to non-controlling interests

574

271

664

586

Income tax provision

366

426

25

547

Interest expense, net of capitalized interest

287

237

542

466

Interest and dividend income

(19

)

(31

)

(35

)

(68

)

Other expense (income), net

14

1

40

(19

)

Income from operations

$

4,290

$

2,530

$

802

$

3,491

Adjustments to reconcile income from operations to Consolidated Adjusted EBITDA:

Depreciation, amortization and accretion expense

380

329

753

641

Loss (gain) from changes in fair value of commodity and foreign exchange (“FX”) derivatives, net (1)

(2,900

)

(1,479

)

2,509

(917

)

Amortization of deferred NPNS assets and liabilities

(5

)

—

(5

)

—

Total non-cash compensation expense

39

35

78

72

Other operating costs and expenses

—

1

—

1

Consolidated Adjusted EBITDA

$

1,804

$

1,416

$

4,137

$

3,288

Consolidated Adjusted EBITDA is commonly used as a supplemental financial measure by our management and external users of our Consolidated Financial Statements to assess the financial performance of our assets without regard to financing methods, capital structures, or historical cost basis. Consolidated Adjusted EBITDA is not intended to represent cash flows from operations or net income (loss) as defined by U.S. GAAP and is not necessarily comparable to similarly titled measures reported by other companies.

We believe Consolidated Adjusted EBITDA provides relevant and useful information to management, investors and other users of our financial information in evaluating the effectiveness of our operating performance in a manner that is consistent with management’s evaluation of financial and operating performance.

Consolidated Adjusted EBITDA is calculated by taking net income (loss) attributable to Cheniere before net income attributable to non-controlling interests, interest expense, net of capitalized interest, taxes, depreciation, amortization and accretion expense, and adjusting for the effects of certain non-cash items, other non-operating income or expense items, and other items not otherwise predictive or indicative of ongoing operating performance, including the effects of modification or extinguishment of debt, impairment expense, gain or loss on disposal of assets, changes in the fair value of our commodity and FX derivatives prior to contractual delivery or termination, amortization of deferred NPNS assets and liabilities, and non-cash compensation expense. Changes in the fair value of commodity and FX derivatives and amortization of deferred NPNS assets and liabilities are considered in determining Consolidated Adjusted EBITDA given that the timing of recognizing gains and losses on these derivative contracts differs from the recognition of the related item economically hedged. We believe the exclusion of these items enables investors and other users of our financial information to assess our sequential and year-over-year performance and operating trends on a more comparable basis and is consistent with management’s own evaluation of performance.

Adjusted Net Income

The following table reconciles our Adjusted Net Income to U.S. GAAP results for the three and six months ended June 30, 2026 and 2025 (in millions):

Three Months Ended June 30,

Six Months Ended June 30,

2026

2025

2026

2025

Net income (loss) attributable to Cheniere

$

3,068

$

1,626

$

(434

)

$

1,979

Loss (gain) from changes in fair value of commodity and FX derivatives, net (1)

(2,900

)

(1,479

)

2,509

(917

)

Amortization of deferred NPNS assets and liabilities

(5

)

—

(5

)

—

Adjustments to net income (loss) attributable to Cheniere related to the above reconciling item:

Income taxes(2)

207

272

(378

)

171

Non-controlling interests

262

79

(54

)

59

Adjusted Net Income

$

632

$

498

$

1,638

$

1,292

Adjusted Net Income is calculated by taking net income (loss) attributable to Cheniere and excluding the effects of non-cash changes in the fair value of agreements accounted for as derivative instruments and amortization of deferred NPNS assets and liabilities, net of the associated non-controlling interests and income tax effects.

Given that the timing of recognizing gains and losses on derivative contracts differs from the recognition of the related item economically hedged, we believe the exclusion of the effect of changes in the fair value of our commodity and FX derivatives and amortization of deferred NPNS assets and liabilities enables investors and other users of our financial information to assess our sequential and year-over-year performance and operating trends on a more comparable basis and is consistent with management’s own evaluation of performance. Adjusted Net Income is not intended to represent net income (loss) as defined by U.S. GAAP and is not necessarily comparable to similarly titled measures reported by other companies.

Consolidated Adjusted EBITDA and Distributable Cash Flow

The following table reconciles our actual Consolidated Adjusted EBITDA and Distributable Cash Flow to Net income (loss) attributable to Cheniere for the three and six months ended June 30, 2026 and forecast amounts for full year 2026 (in billions):

Three Months Ended June 30,

Six Months Ended June 30,

Full Year

2026

2026

2026

Net income (loss) attributable to Cheniere

$

3.07

$

(0.43

)

$

1.6

-

$

2.0

Net income attributable to non-controlling interests

0.57

0.66

1.3

-

1.3

Income tax provision

0.37

0.03

0.2

-

0.3

Interest expense, net of capitalized interest

0.29

0.54

1.1

-

1.1

Depreciation, amortization and accretion expense

0.38

0.75

1.5

-

1.5

Other income, financing costs, and certain non-cash operating expenses

(2.87

)

2.59

2.1

-

2.1

Consolidated Adjusted EBITDA

$

1.80

$

4.14

$

7.90

-

$

8.40

Interest expense, net of interest income, capitalized interest and amortization

(0.25

)

(0.48

)

(1.0

)

-

(1.0

)

Maintenance capital expenditures

(0.03

)

(0.06

)

(0.2

)

-

(0.2

)

Income tax (excludes deferred taxes)(1)

(0.06

)

(0.10

)

(0.1

)

-

(0.2

)

Other income

(0.03

)

(0.06

)

(0.1

)

-

(0.1

)

Consolidated Distributable Cash Flow

$

1.43

$

3.44

$

6.40

-

$

6.80

Distributable Cash Flow attributable to non-controlling interests

(0.28

)

(0.60

)

(1.1

)

-

(1.0

)

Cheniere Distributable Cash Flow

$

1.17

$

2.84

$

5.30

-

$

5.80

Distributable Cash Flow is defined as cash generated from the operations of Cheniere and its subsidiaries and adjusted for non-controlling interests. The Distributable Cash Flow of Cheniere’s subsidiaries is calculated by taking the subsidiaries’ EBITDA less interest expense, net of capitalized interest, taxes, maintenance capital expenditures and other non-operating income or expense items, and adjusting for the effect of certain non-cash items and other items not otherwise predictive or indicative of ongoing operating performance, including the effects of modification or extinguishment of debt, amortization of debt issue costs, premiums or discounts, impairment of equity method investment and deferred taxes. Cheniere’s Distributable Cash Flow includes 100% of the Distributable Cash Flow of Cheniere’s wholly-owned subsidiaries. For subsidiaries with non-controlling investors, our share of Distributable Cash Flow is calculated as the Distributable Cash Flow of the subsidiary reduced by the economic interest of the non-controlling investors as if 100% of the Distributable Cash Flow were distributed in order to reflect our ownership interests and our incentive distribution rights, if applicable. The Distributable Cash Flow attributable to non-controlling interests is calculated in the same method as Distributions to non-controlling interests as presented on our Consolidated Statements of Stockholders’ Equity (Deficit) in our Forms 10-Q and Forms 10-K filed with the Securities and Exchange Commission. This amount may differ from the actual distributions paid to non-controlling investors by the subsidiary for a particular period.

We believe Distributable Cash Flow is a useful performance measure for management, investors and other users of our financial information to evaluate our performance and to measure and estimate the ability of our assets to generate cash earnings after servicing our debt, paying cash taxes and expending sustaining capital, that could be considered for deployment by our Board of Directors pursuant to our capital allocation plan, such as by way of common stock dividends, stock repurchases, retirement of debt, or expansion (growth) capital expenditures1. Distributable Cash Flow is not intended to represent cash flows from operations or net income (loss) as defined by U.S. GAAP and is not necessarily comparable to similarly titled measures reported by other companies.

We have not made any forecast of net income (loss) on a run-rate basis, which would be the most directly comparable measure under U.S. GAAP, in part because net income (loss) includes the impact of derivative transactions, which cannot be determined at this time, and we are unable to reconcile differences between run-rate Distributable Cash Flow and net income (loss).

More News From Cheniere Energy, Inc.

Wall Street analysts expect Cheniere Energy (LNG - Free Report) to post quarterly earnings of $2.80 per share in its upcoming report, which indicates a year-over-year decline of 61.6%. Revenues are expected to be $5.03 billion, up 8.4% from the year-ago quarter.

The current level reflects a downward revision of 2% in the consensus EPS estimate for the quarter over the past 30 days. This demonstrates how the analysts covering the stock have collectively reappraised their initial projections over this period.

Ahead of a company's earnings disclosure, it is crucial to give due consideration to changes in earnings estimates. These revisions serve as a noteworthy factor in predicting potential investor reactions to the stock. Numerous empirical studies consistently demonstrate a strong relationship between trends in earnings estimate revision and the short-term price performance of a stock.

While investors usually depend on consensus earnings and revenue estimates to assess the business performance for the quarter, delving into analysts' forecasts for certain key metrics often provides a more comprehensive understanding.

With that in mind, let's delve into the average projections of some Cheniere Energy metrics that are commonly tracked and projected by analysts on Wall Street.

Based on the collective assessment of analysts, 'Revenues- LNG' should arrive at $5.14 billion. The estimate indicates a change of +13.9% from the prior-year quarter.

The consensus estimate for 'Revenues- Other' stands at $67.94 million. The estimate suggests a change of -26.2% year over year.

It is projected by analysts that the 'Revenues- Regasification' will reach $34.22 million. The estimate suggests a change of +0.6% year over year.

View all Key Company Metrics for Cheniere Energy here>>>

Shares of Cheniere Energy have demonstrated returns of +4.9% over the past month compared to the Zacks S&P 500 composite's +1.7% change. With a Zacks Rank #3 (Hold), LNG is expected to mirror the overall market performance in the near future. You can see the complete list of today's Zacks Rank #1 (Strong Buy) stocks here >>>> .