Capstone Green Energy Holdings Inc. has reported fourth quarter and annual revenues of $27.1 million and $85.6 million respectively for fiscal year 2025, compared to 2024 fourth quarter and annual revenues of $24.3 million and $91.2 million respectively. The company said in its report that the fourth-quarter revenue improved by $2.8 million year-over-year, driven by increased demand for products and services, as well as improved rental utilization rates within the company’s Energy as a Service (EaaS) revenue stream. Slow product sales in the first half of the fiscal year caused a decrease of $5.7 million for the year. This was mainly due to restructuring hesitancy and instability in Europe, it said. Gross profit for the fourth quarter of 2025 was $7.5 million, up $4.9 million from the fourth quarter of fiscal 2024. The company recorded a net loss of $0.1 million, compared to a net loss of $5.3 million for the same period in fiscal 2024. Adjusted earnings before interest, taxes, depreciation, and amortization (EBITDA) for the fourth quarter of fiscal 2025 was $2.8 million, up $0.8 million from the fourth quarter of fiscal 2024. This improvement was mainly due to better gross margins and lower operating expenses, it said. Gross profit for FY2025 was $23.3 million, up from $14.3 million for FY2024, due to sales mix shift and price hikes. Net loss was $7.2 million, swinging from FY2024’s net income of $7.4 million, which included a $32.5 million reorganization gain. Excluding this gain, the net loss was cut by $17.9 million, driven by better gross profit, lower expenses, and reduced costs. Adjusted EBITDA rose to $7.9 million from negative $0.5 million for FY2024, including non-recurring charges related to restructuring, litigation, restatement, and SEC investigations, which concluded in early FY2026. “The company’s full-year results reflect the focus on financial health

Cheniere Energy Partners LP (CQP), part of Cheniere Energy Inc. (Cheniere), is offering $1 billion of senior notes due 2035 with a yearly interest of 5.55 percent. “The CQP 2035 Notes will be issued at a price equal to 99.731 percent of par”, CQP said in a press release. Cheniere Partners expects to close the offering July 10. “Cheniere Partners intends to contribute the proceeds from the offering to its subsidiary, Sabine Pass Liquefaction, LLC, to be used to redeem a portion of the outstanding aggregate principal amount of its senior secured notes due 2026”, the statement added. “The CQP 2035 Notes will rank pari passu in right of payment with the existing senior notes at Cheniere Partners, including the senior notes due 2029, the senior notes due 2031, the senior notes due 2032, the senior notes due 2033 and the senior notes due 2034”, it said. Cheniere Partners owns the Sabine Pass LNG terminal in Cameron Parish, Louisiana. The terminal has a production capacity of about 30 million metric tons per annum (MMtpa). It also has regasification facilities that include five LNG storage tanks, vaporizers and three marine berths. Cheniere Partners also owns the Creole Trail Pipeline, which interconnects Sabine Pass LNG with several interstate and intrastate pipelines. Houston, Texas-based Cheniere, which owns 100 percent of the general partner stake and 48.6 percent of the limited partner interest in CQP, reported $10.55 billion in available liquidity at the end of the first quarter. On June 24 Cheniere announced a positive FID (final investment decision) to add two “midscale” trains to the Corpus Christi LNG facility in South Texas. The two trains will raise the terminal’s capacity by over 3 MMtpa. In July 2023 the United States Department of Energy (DOE) granted CCL Midscale Trains 8 & 9 authorization to export to countries

Ameren Missouri, a subsidiary of Ameren Corp., has filed an application with the Missouri Public Service Commission to build an 800-megawatt (MW) simple-cycle natural gas energy center. The company said in a media release that the project would be complemented by Ameren Missouri’s first large-scale battery storage facility. The project, located in Jefferson County, Missouri, is named the Big Hollow Energy Center. “This is the next step to deliver on our strategy to invest in energy infrastructure for our customers’ benefit and provide a balanced generation portfolio”, Mark Birk, chairman and president of Ameren Missouri, said. “As we transition our generation for the future, we’ll continue to serve our customers with the reliable energy they expect while also preparing for anticipated increases in demand”. The Big Hollow Energy Centre is expected to serve as a backup energy source by 2028, similar to Castle Bluff, providing energy during extreme weather conditions and supporting renewable energy sources. On-site, Ameren Missouri will install its first large-scale lithium-ion batteries, capable of being charged when excess energy is available. The 400-MW battery storage is quick to activate, supporting thousands of homes and grid reliability during peak times. Ameren Missouri plans 1,000 MW of battery storage by 2030 and 1,800 MW by 2042, the company said. Ameren added that the two facilities will operate independently. Both will also take advantage of the existing infrastructure on Ameren Missouri-owned land. The identified site, which Ameren Missouri already owns, has existing infrastructure and transmission line access, reducing overall construction time, it said. “It is crucial to have a balanced mix of generation technologies and equally important to strategically locate them across the region”, Ajay Arora, senior vice president and chief development officer at Ameren Missouri, added. “This approach maximizes the energy output from these resources”. Rob Dixon, senior director

The Bureau of Land Management (BLM) has approved a proposed Northwestern Energy pipeline to carry natural gas from Helena to Three Forks, as well as several geothermal expansion and research projects by Ormat Technologies in Nevada. “These projects mark important progress in expanding both traditional and renewable energy infrastructure on public lands”, the Interior Department sub-agency said in an online statement. The 74-mile, 16-inch pipeline benefited from emergency permitting procedures introduced by the Interior last April in response to President Donald Trump’s National Energy Emergency declaration in January. The Interior has allowed environmental assessments that normally take up to one year to be completed in about 14 days, it said in a statement April 23. NorthWestern Energy submitted its proposal June 10 for a 30-year right of way, according to the BLM’s project information page. “The pipeline route includes approximately nine miles of BLM-managed public lands and will follow an existing utility corridor to minimize new ground disturbance and ecological disruption”, the BLM statement said. It will be built in phases between spring 2026 and fall 2029. “Preparatory activities, including increased survey traffic and engineering assessments, are expected to begin in 2025”, the BLM said. In Nevada, the McGinness Hills Geothermal Optimization Project will upgrade and expand three existing Lander County power plants. “Enhancements include new production wells, advanced heat exchangers, upgraded cooling fans, and the addition of a 15-megawatt solar photovoltaic field – aimed at improving overall efficiency and increasing output beyond the current 193 megawatts”, the BLM said. The Diamond Flat Geothermal Project will drill test wells and conduct geothermal resource confirmation activities on federally leased lands near Fallon. Ormat will undertake up to 33 shallow direct push holes and up to four temperature gradient wells to better outline the extent of the geothermal resource. Based on the results,

In an EBW Analytics Group report sent to Rigzone by the EBW team on Tuesday, Eli Rubin, an energy analyst at the company, highlighted a “collapse” in the August natural gas contract on Monday. The contract closed at $3.456 per million British thermal units (MMBtu) yesterday, which marked a 28.3 cent, or 7.6 percent drop, from the previous close, the report outlined.  “Yesterday’s natural gas price implosion fully erased Friday’s gains, with strong supply readings, milder Week 3 weather (particularly in Texas and the Southeast), and ongoing Henry Hub spot market softness dragging down the curve,” Rubin said in the report. “LNG bright spots are beginning to emerge, however, with Corpus Christi nominations rising to match a facility high, and LNG Canada loading its first cargo. Early-cycle U.S. LNG demand readings are already 1.9 billion cubic feet per day (Bcfpd) above the June average,” he added. “Critical support near $3.40 per MMBtu (last Thursday’s intraday low) may be determinative for the NYMEX front-month. If support can hold, LNG solidifies at higher levels, and elevated late June production readings decline, expanding Week 2 CDDs [Cooling Degree Days] surpassing the late June heat wave could propel upside over the next 7-10 days,” Rubin went on to state. “If support fails, however, it may open the door to another leg lower at the front of the NYMEX curve,” Rubin warned in the report. In an EBW Analytics Group report sent to Rigzone by the EBW team on Monday, Rubin highlighted that natural gas retreated after Friday’s gain. The report pointed out that the August natural gas contract closed at $3.739 per MMBtu on Friday. This represented a 21.3 cent, or 6.0 percent, rise compared to the previous close, the report outlined. “While the August natural gas contract rose 21.3 cents on Friday after plunging 42.3

A coalition of financial, technical and environmental partners has launched a framework that aims to help investors, lenders, and oil and gas companies integrate methane and flaring performance into debt financing. The Methane Finance Working Group, an initiative launched at COP28 in 2023, released guidance to “deliver and deploy market-tested finance mechanisms that facilitate decarbonization across the oil and gas sector, while expanding the opportunities to achieve measurable methane emission reductions,” the Environmental Defense Fund (EDF) said in a statement. The guidance provided by the group “includes a third-party verification process from trusted scientific and engineering experts, establishing an independent benchmark to evaluate and assess company methane performance during the financing process,” according to the statement. The guidance provides recommendations to adapt market-tested financial instruments to structure bonds, use of proceeds instruments, loans and other conventional debt transactions targeting methane and flaring reductions from the oil and gas industry. It is designed to serve both lenders and borrowers, the statement said. Although the technology for methane reduction exists, capital flows remain limited due to structural barriers. Many companies lack access to finance tailored to methane mitigation, while investors struggle to assess emissions performance consistently, the EDF said. Similar bonds have been utilized successfully in other sectors, such as global power utilities, which has cumulatively issued $500 billion in labeled bonds, the EDF noted. Methane performance is a growing factor in global liquefied natural gas (LNG) markets, where buyers are increasingly evaluating upstream emissions when sourcing gas. As international scrutiny over lifecycle emissions intensifies, financial and operational methane transparency has become a competitive differentiator for producers and exporters, according to the statement. “Reducing methane emissions across the oil and gas industry is one of the fastest and most effective ways to slow climate warming in the near term. But the financial