Category: Energy

  • MIL-OSI China: Negotiations on Gaza truce deal begin in Cairo

    Source: China State Council Information Office

    People welcome a released Palestinian prisoner in the southern Gaza Strip city of Khan Younis, on Feb. 27, 2025. [Photo/Xinhua]

    Israeli and Qatari delegations arrived in the Egyptian capital of Cairo on Thursday for Gaza ceasefire talks, with the participation of U.S. representatives, according to Egypt’s State Information Service (SIS).

    The SIS said in a statement that the concerned parties have begun intensive discussions “on the next stages of the ongoing Gaza truce deal,” while addressing ways to ensure the implementation of the previously agreed-upon understandings.

    The negotiators also touched upon means to enhance the delivery of humanitarian aid to the Gaza Strip, as part of the efforts to alleviate the suffering of its people and further support stability in the region, it added.

    Earlier in the day, the Israeli Prime Minister’s Office announced that an Israeli negotiating delegation was sent to Cairo to continue the ceasefire talks, without providing further details.

    The announcement came after the final exchange of Israeli hostages and Palestinian prisoners under the first phase of the truce was completed overnight between Wednesday and Thursday. The 42-day initial phase of the three-stage agreement is set to expire on Saturday.

    In response to a question about whether the delegation heading to Cairo will discuss moving on to a second phase, Israeli Foreign Minister Gideon Sa’ar said, “Our delegation will go to Cairo and see whether we have common ground to negotiate.”

    “We said we are ready to extend the framework in return for the release of more hostages,” he added. Israeli media said the minister was referring to the framework of phase one.

    Earlier on Thursday, Israeli Energy Minister Eli Cohen told Israeli media that 59 hostages remain in Gaza and securing their release remains a top priority.

    Hamas said on Thursday it was ready to begin talks on the second phase and that the only way the remaining hostages in Gaza would be freed is through commitment to the ceasefire.

    The ongoing Gaza ceasefire agreement, which took effect on Jan. 19, was brokered by Qatar and Egypt, with support from the United States.

    MIL OSI China News

  • MIL-OSI USA: Hoeven Outlines Efforts to Reverse Biden Regulatory Onslaught, Make U.S. Energy Dominant

    US Senate News:

    Source: United States Senator for North Dakota John Hoeven

    02.26.25

    Senator’s CRA Resolution to Block Biden Natural Gas Tax Set for Final Passage in U.S. Senate Tomorrow

    WASHINGTON – During remarks delivered on the floor of the U.S. Senate today, Senator John Hoeven outlined efforts to reverse the Biden administration’s regulatory onslaught on U.S. domestic energy production:

    • In particular, Hoeven highlighted his Congressional Review Act (CRA) resolution to block implementation of Biden’s Natural Gas Tax, which passed as part of Democrats’ reckless tax-and-spend bill that passed in 2022.
      • The Senate began voting on Hoeven’s resolution today, with final passage expected to occur tomorrow.
    • Following his remarks, Hoeven voted to uphold the national energy emergency, which was declared by President Trump to unlock additional authorities empowering the development of U.S. energy resources and the infrastructure needed to get energy to market.
      • The national emergency was upheld by a vote of 52 to 47.

    “We’re working with President Trump to unleash America’s full energy potential and truly make our nation energy dominant. Energy security is national security and it is vitally important for our country,” said Hoeven. “We’ve worked diligently in the Senate to swiftly confirm President Trump’s cabinet officials, and we continue to do that. We made it a priority to ensure the president’s department heads are in place as we work to empower the U.S. to produce more energy from all of its abundant and affordable coal, oil, and gas reserves.

    “We also continue legislative efforts to get our country back to energy dominance. Soon, the Senate will vote on my resolution to nullify the Democrats’ natural gas tax rule, using the Congressional Review Act… Essentially, this puts a 5 percent or more added tax on natural gas. Now, think about that. Everybody uses natural gas to heat their homes, cook their meals and for many other purposes as well. It’s a tax on every consumer, and it’s regressive, hitting low-income individuals the hardest. This of course also has a disproportionate impact on small oil and gas producers in states like North Dakota, Montana and others.

              “Instead of new taxes that will curtail production, we need to support innovation and empower the kind of technology development that has enabled us to reduce emissions while producing more natural gas. That’s the answer, and it’s exactly what President Trump and Republicans have done and will continue to do.

              “We’re also working with the Trump administration to replace the Biden administration’s rules that closed off access to vast areas of taxpayer-owned energy resources… This is about taking the handcuffs off our energy producers and empowering them to increase supply and help bring down prices for American families and businesses. There is an energy component in every product and service we consume. When we make energy more plentiful and bring down that price, that helps reduce inflation, grow our economy, create more jobs and opportunities and, in fact, not only provide for our national security but help our allies as well.”

    MIL OSI USA News

  • MIL-OSI USA: Senate Passes Hoeven-Sponsored Resolution to Block Biden Natural Gas Tax, Protect Against Cost Increases

    US Senate News:

    Source: United States Senator for North Dakota John Hoeven

    02.27.25

    CRA Resolution Goes to President Trump for Signature

    WASHINGTON – Senator John Hoeven (R-N.D.) today secured Senate passage of his Congressional Review Act (CRA) resolution of disapproval to block implementation of President Biden’s Natural Gas Tax, which passed as part of the Democrats’ reckless tax-and-spend bill in 2022. The Senate approved the resolution by a vote of 52 to 47, and with Congressman August Pfluger’s (R-Texas) companion legislation having passed the House yesterday, the resolution now goes to President Trump to be signed into law.

    “We depend on natural gas for a wide array of needs, from manufacturing to home heating and cooking, all of which were going to be more expensive as a result of President Biden’s Natural Gas Tax,” said Senator Hoeven. “We’ve now moved our legislation through both chambers, and we look forward to it being signed by President Trump. This is an important milestone in our efforts to roll back the Biden administration’s harmful Green New Deal policies, unleash our domestic energy potential and make our nation truly energy dominant.”

    This legislation comes as part of Hoeven’s broader efforts to unlock America’s energy potential and rescind the wide array of costly taxes and regulations imposed under President Biden. Among other priorities, Hoeven is working to:

    • Improve access to taxpayer-owned energy resources.
    • Streamline the approval process for energy development and the construction of infrastructure needed to get energy to market.
    • Reduce the cost of energy production, fight inflation and bring down prices for American consumers.

    MIL OSI USA News

  • MIL-OSI USA: Wyden, Merkley Join Bill to Codify DOJ’s Office of Environmental Justice

    US Senate News:

    Source: United States Senator Ron Wyden (D-Ore)

    February 27, 2025

    Washington, D.C. U.S. Senators Ron Wyden and Jeff Merkley said today they are joining legislation that would permanently codify the Office of Environmental Justice within the Department of Justice’s Environment and Natural Resources Division, in the wake of Attorney General Pam Bondi’s recent order eliminating all environmental justice efforts at the department.

    Bondi’s directive followed Donald Trump’s executive order ending all Diversity, Equity, and Inclusion initiatives across federal agencies. As a result, programs combating pollution in communities of color, indigenous people, and low-income areas were effectively shut down in Oregon and nationwide. The Trump administration also terminated several division attorneys responsible for prosecuting environmental violations. 

    “The attack on environmental justice is an attack on the millions of Americans relying on clean air and clean water across our country,” Wyden said. “Federal agencies have a responsibility to protect our communities – not tear down solutions that keep people healthy for generations. Trump and his oil-loving cronies are not just making the climate crisis worse. They are also harming the most vulnerable communities in America.” 

    “Everyone, in every corner of Oregon—and across the country—deserves clean air, clean water, and protection from climate chaos. Unfortunately, the dismantling of environmental justice efforts by the Trump Administration has left our most vulnerable communities exposed to even greater risks,” Merkley said. “The Empowering and Enforcing Environmental Justice Act addresses these disparities by codifying vital protections, holding polluters accountable, and ensuring that every community, especially those most impacted by climate disasters and toxic pollution, has the necessary tools to secure a healthier, safer future.”

    The legislation would strengthen efforts at the Department of Justice to enforce environmental laws, hold polluters accountable, and support state and local environmental enforcement capacity. The Empowering and Enforcing Environmental Justice Act would also authorize $50 million in annual grant funding to assist state and local governments with their own environmental enforcement efforts.

    Senator Wyden is a longtime champion of environmental justice. In 2019, Wyden and his colleagues introduced legislation to overhaul the federal energy tax code, create jobs, and combat climate change. In 2022, Wyden’s Clean Energy for America Act was enacted as part of the Inflation Reduction Act – significantly lowering carbon emissions while reducing energy costs. In 2024, Wyden announced a federal investment of $20 million for the Confederated Tribes of Grand Ronde to build a safe, accessible shelter for communities affected by the rising climate crisis. 

    The bill was introduced by U.S. Senator Alex Padilla, D-Calif., and in addition to Wyden and Merkley, the bill was co-sponsored by Senators Richard Blumenthal, D-Conn., Cory Booker, D-N.J., Tammy Duckworth, D-Ill., Edward J. Markey, D-Mass., Bernard Sanders, I-Vt., Adam Schiff, D-Calif., Chris Van Hollen, D-Md, and U.S. Representatives Yassamin Ansari, D-Ariz., Suzanne Bonamici, D-Ore., Jasmine Crockett, D-Texas., Diana DeGette, D-Colo., Tim Kennedy, D-N.Y., Raja Krishnamoorthi, D-Ill., Doris Matsui, D-Calif., LaMonica McIver, D-N.J., Eleanor Holmes Norton, D-D.C., Dina Titus, D-Nev., and Rashida Tlaib, D-Mich.

    The text of the bill is here.

    MIL OSI USA News

  • MIL-OSI: Prospera Announces Monthly Operations Update and Increase to Term Loan

    Source: GlobeNewswire (MIL-OSI)

    CALGARY, Alberta, Feb. 27, 2025 (GLOBE NEWSWIRE) — Prospera Energy Inc. (TSX.V: PEI, OTC: GXRFF) (“Prospera“, “PEI” or the “Corporation“)

    Prospera Energy remains committed to providing stakeholders with transparent, timely, and data-driven updates on operational performance and field developments. This monthly report delivers key insights into the company’s production trends, optimization initiatives, and strategic advancements. All production figures represent the Company’s gross sales, reported in accordance with NI 51-101 and applicable industry standards.

    Production averaged 680 boe/d (92% oil) from February 1st-25th, with production peaking on February 25th at 798 boe/d (92% oil), despite extreme winter conditions including record low wind chills reaching -47°C on several days. This production growth reflects the Company’s continued efforts to optimize well performance and bring additional production online.

    The company continues advancing its Hearts Hill workover program with seven of eleven wells now completed, achieving capital efficiency of less than $5,000 per boe/d. In mid-February, Prospera deployed a second service rig to accelerate its Luseland workover program with three of ten wells now completed. The program’s first three wells have come in 24% under budget, while still in the clean-up and load fluid recovery phase.

    The company is specifically targeting high-impact Luseland workovers, including wells with significant reservoir and production potential that have remained offline for the last 10 to 15 years. These wells were previously inactive due to lower commodity prices, lack of operational focus, limited capital availability of past operators, and outdated heavy oil downhole technology which has since seen a step change during this timeframe and which Prospera can now leverage. Additionally, the Company has initiated a review of several enhanced oil recovery techniques, including polymer flooding, steam injection, injector conversions to improve waterflood sweep, and facility debottlenecking to optimize production efficiency.

    Reaffirming its commitment to strengthening its financial position, Prospera has successfully negotiated structured payment plans and arrangements with its top 50 vendors ranked by outstanding accounts payable arrears. This initiative marks a significant step toward reducing liabilities, enhancing cash flow management, and fostering long-term vendor partnerships—ensuring the Company can execute its development plans with greater financial flexibility.

    The company continues to make significant strides in addressing MER and AER non-compliances including spill pile clean-ups, well and lease signage, mineral lease reacquisitions, general housekeeping, and annulus/packer fixes, ensuring adherence to regulatory standards while maintaining operational efficiency. These compliance efforts remain a top priority as Prospera reinforces its commitment to responsible resource development.

    The pipeline cutout failure analysis and third-party engineering review for both Hearts Hill pipeline failures have been completed and shared with the appropriate regulatory bodies. The conclusions from these evaluations have been incorporated into Prospera’s field-wide development strategy, as well as its abandonment, reclamation, and turnaround initiatives.

    In Brooks, the company continues to accelerate well production by increasing fluid level drawdown, implementing casing gas compression to alleviate pressure on the reservoir, and enhanced wax and scale mitigation strategies. These efforts have led to increased production, with additional optimization capacity available on these fronts. Preparatory work in Brooks is ongoing, including evaluations of acid fracs versus cross-linked gel fracs and the most effective matrix stimulation techniques for the Pekisko wells. AFE’s have been finalized for various projects and are ready to be capitalized as part of the company’s development plans.

    The company has completed extensive reviews of the nine horizontal wells drilled in 2023 in the Cuthbert pool, as only three of the wells are performing to expectations. The six lower-producing wells have been analyzed through reservoir engineering, geological assessments, and drilling post-mortem analysis. Plans are in place to conduct workovers on four of these wells over time, with one specific workover scheduled for later in Q1.

    Replacement of worn-out field equipment has accelerated, with new and rebuilt engine installations being completed across all fields. Plans are in place to purchase additional new and rebuilt engines as wells are brought online. Lease operating cost reviews are now being conducted more frequently, with a current focus on optimizing electricity costs, flushby costs, and the transportation of oil from our batteries to sales points.

    Loan Amendment Update
    The Corporation announces a further amendment to its $11,000,000 promissory note, originally dated July 7, 2024, in collaboration with its principal lender. Following previous increases, an additional $1,550,000 has been added, bringing the total principal amount to $14,500,000. The note retains its original terms, including a 12% interest rate and a two-year maturity, with no other changes. This amendment remains subject to acceptance by the TSXV.

    About Prospera

    Prospera Energy Inc. is a publicly traded Canadian energy company specializing in the exploration, development, and production of crude oil and natural gas. Headquartered in Calgary, Alberta, Prospera is dedicated to optimizing recovery from legacy fields using environmentally safe and efficient reservoir development methods and production practices. The company’s core properties are strategically located in Saskatchewan and Alberta, including Cuthbert, Luseland, Hearts Hill, and Brooks. Prospera Energy Inc. is listed on the TSX Venture Exchange under the symbol PEI and the U.S. OTC Market under GXRFF.

    Prospera reports gross production at the first point of sale, excluding gas used in operations and volumes from partners in arrears, even if cash proceeds are received. Gross production represents Prospera’s working interest before royalties, while net production reflects its working interest after royalty deductions. These definitions align with ASC 51-324 to ensure consistency and transparency in reporting.

    For Further Information:

    Shawn Mehler, PR
    Email: investors@prosperaenergy.com

    Chris Ludtke, CFO
    Email: cludtke@prosperaenergy.com

    Shubham Garg, Chairman of the Board
    Email: sgarg@prosperaenergy.com

    FORWARD-LOOKING STATEMENTS

    This news release contains forward-looking statements relating to the future operations of the Corporation and other statements that are not historical facts. Forward-looking statements are often identified by terms such as “will,” “may,” “should,” “anticipate,” “expects” and similar expressions. All statements other than statements of historical fact included in this release, including, without limitation, statements regarding future plans and objectives of the Corporation, are forward-looking statements that involve risks and uncertainties. There can be no assurance that such statements will prove to be accurate and actual results and future events could differ materially from those anticipated in such statements.

    Although Prospera believes that the expectations and assumptions on which the forward-looking statements are based are reasonable, undue reliance should not be placed on the forward-looking statements because Prospera can give no assurance that they will prove to be correct. Since forward-looking statements address future events and conditions, by their very nature they involve inherent risks and uncertainties. Actual results could differ materially from those currently anticipated due to a number of factors and risks. These include, but are not limited to, risks associated with the oil and gas industry in general (e.g., operational risks in development, exploration and production; delays or changes in plans with respect to exploration or development projects or capital expenditures; the uncertainty of reserve estimates; the uncertainty of estimates and projections relating to production, costs and expenses, and health, safety and environmental risks), commodity price and exchange rate fluctuations and uncertainties resulting from potential delays or changes in plans with respect to exploration or development projects or capital expenditures.

    The reader is cautioned that assumptions used in the preparation of any forward-looking information may prove to be incorrect. Events or circumstances may cause actual results to differ materially from those predicted, as a result of numerous known and unknown risks, uncertainties, and other factors, many of which are beyond the control of Prospera. As a result, Prospera cannot guarantee that any forward-looking statement will materialize, and the reader is cautioned not to place undue reliance on any forward- looking information. Such information, although considered reasonable by management at the time of preparation, may prove to be incorrect and actual results may differ materially from those anticipated. Forward-looking statements contained in this news release are expressly qualified by this cautionary statement. The forward-looking statements contained in this news release are made as of the date of this news release, and Prospera does not undertake any obligation to update publicly or to revise any of the included forward-looking statements, whether as a result of new information, future events or otherwise, except as expressly required by Canadian securities law.

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

    The MIL Network

  • MIL-OSI China: Construction begins on Lao section of China-Laos 500 kV power interconnection project

    Source: People’s Republic of China – State Council News

    Construction begins on Lao section of China-Laos 500 kV power interconnection project

    VIENTIANE, Feb. 27 — The launch ceremony for the construction of the Lao section of the China-Laos 500 kV power interconnection project was held in the Lao capital Vientiane on Wednesday.

    Once operational, the project is set to significantly enhance electricity interconnection and mutual assistance between China and Laos.

    Lao Prime Minister Sonexay Siphandone, Lao government officials, and representatives from the Chinese government and enterprises attended the launch ceremony.

    Speaking at the meeting, Lao Minister of Energy and Mines Phoxay Sayasone said that the project is a strategic energy project that will better support the economic development of Laos and further expand the interconnection of power grids and electricity mutual assistance between Laos and southern provinces of China.

    Also speaking at the event, Chinese Ambassador to Laos Fang Hong stated that the project is another major achievement in deepening practical cooperation between China and Laos, following the China-Laos Railway, as part of their joint efforts in building the Belt and Road.

    “As the pioneer of economic and social development, electricity plays a crucial role in improving people’s well-being and fostering regional prosperity. We must continue to implement the important consensus reached by the leaders of both parties and countries, with the construction of the China-Laos Economic Corridor as the central focus, while further strengthening cooperation in energy and electricity through power grid interconnection,” she added.

    The China-Laos 500 kV power interconnection project is a key initiative outlined in the action plan to build a China-Laos community with a shared future, with completion and operation scheduled for 2026. Once operational, the project is expected to enable a two-way power mutual assistance capacity of 1.5 million kW and facilitate the transmission of about 3 billion kWh of clean electricity.

    The Lao section of the project is being developed by Electricite du Laos Transmission Company Limited, while the Chinese section is managed by China Southern Power Grid Company.

    MIL OSI China News

  • MIL-OSI USA: Making Innovation Happen: New IN² Cohort Focuses on Advanced Energy Implementation

    Source: US National Renewable Energy Laboratory


    Teens sit outside of Ponderosa High School in Coconino County, Arizona, in the garden that students created and maintained. Photo from Ponderosa High School

    At Ponderosa High School in Coconino County, Arizona, students are determined to overcome obstacles on their path to graduation. Some arrive behind on credits, while others are returning to the classroom after time away. The alternative school offers more than a second chance—it is an opportunity for transformation.

    That is just one reason why Coconino County Schools selected Ponderosa as the focus of an advanced energy initiative through the Wells Fargo Innovation Incubator (IN2), managed by the U.S. Department of Energy’s National Renewable Energy Laboratory (NREL).

    “Our goal at Ponderosa is to create opportunities that shift perspectives—helping students see a hopeful future and discover industries they may not have considered,” Ponderosa High Principal Les Hauer said. “The energy future is full of possibility, and this initiative helps us show students what’s possible while preparing them to succeed.”

    Coconino County is one of 10 members of IN2’s latest cohort, which marked a significant milestone for the program. For the first time in its 10-year history, IN2 shifted its focus from supporting startups to implementing energy technologies within established organizations.

    Before pitching their projects in December 2024, participants engaged in months of preparation and education, including technology selection and impact analyses. The pitch session culminated in the cohort presenting their plans to install and use a tool or system within six months, with winners receiving a share of $750,000 in Wells Fargo funding to bring their projects to life.

    “This is a monumental new direction for IN2,” said IN2 Program Manager Sarah Derdowski. “IN2 continues to help startups move forward over the ‘valleys of death,’ but now we also get to support the implementation of innovative technologies and make real progress in building a resilient, adaptable future.”

    Pumpkins grow in the student garden outside of Ponderosa High School. Photo from Ponderosa High School

    The participants in the cohort are:

    • Avangrid
    • Coconino County
    • CBRE
    • Digital Realty
    • Galvanize Real Estate (GRE)
    • Intermountain Health
    • Prime Data Centers
    • Schneider Electric
    • Southern Company
    • University of Colorado Boulder.

    Although some cohort members are large companies, they face unique barriers where IN2’s support is invaluable. During pitch day, one of the presenters made the problem plain: Even large, well-funded organizations may find resistance to innovative technologies if they might compromise profitability.

    “Pursuing new technologies is often seen as a cost and business risk for any size organization,” said Howard Branz, director of science and impact for Galvanize Climate Solutions. “At GRE, our scientists and investors work together to mitigate these risks by piloting technologies in real-world settings where we can test and prove their performance, ensuring that increasing profitability and meeting our metrics go hand-in-hand. The IN2 award allows us to further accelerate the deployment of cutting-edge building technology solutions, advancing our goals.”

    Coconino County’s Teaching Moment

    Coconino County’s ambitious vision stood out among the pitches in early December with its goal of reducing the district’s energy consumption by 40% while creating a replicable school model for the region.

    “We hope to transform our local schools by serving as a demonstration site for retrofitting and energy practices,” Superintendent Cheryl Mango-Paget said.

    Ponderosa High School, located near the Grand Canyon, has about 70 students. The district identified heating, ventilation, and air conditioning (HVAC) as the best opportunity because it could have the greatest impact. The district’s aging air conditioning units are due for replacement, and the hope is that Ponderosa can serve as a blueprint for surrounding schools.

    To achieve that, Coconino County would integrate three technologies in one building. Blue Frontier, a company that graduated from IN2 several years ago, will install a new AC unit that uses liquid desiccant technology developed by NREL. Rensair will improve air quality. And Komfort will address energy through lighting. The single Blue Frontier unit could replace up to 18 AC units already on the building. Estimates done during IN2 show the new systems, at minimum, could cut utility costs by 50%.

    Participants from Coconino County pitch their proposal during the pitch day in early December 2024. Photo by Agata Bogucka, NREL

    “This partnership with NREL and IN2 is a powerful teaching tool,” Hauer said. “We’re giving students a hands-on experience beyond the classroom by letting them observe the installation process.”

    While the students will not install the systems themselves, they will learn from the process and gain insight into future job opportunities in the HVAC and advanced energy industries.

    CBRE’s AC Pivot

    When Jeff Dunbar, senior sustainability director for CBRE, first got involved with IN2, he thought their project would focus on advanced cement. Then he realized they only had six months to implement, so he pivoted to a faster solution: rooftop HVAC units.

    “We replace thousands of rooftop units every year in the U.S.,” Dunbar said. “This became an easy lever for us to pull.”

    CBRE manages more than 7 billion square feet of property around the world and spent more than $33 billion with suppliers last year globally. Once CBRE identified the HVAC direction, NREL helped pinpoint where to go next.

    Jeff Dunbar, senior sustainability director for CBRE, pitches the company’s proposal during the IN2 pitch day. Photo by Agata Bogucka, NREL

    “I stood in a room at NREL and stared at Blue Frontier’s mockup of this technology while an NREL engineer explained how it works,” Dunbar said. “Together, we found our ‘Goldilocks’ site that matches the necessary specs on a building in Delaware.”

    The pilot project will install and test Blue Frontier’s unit on this building in Delaware, with the potential of replicating it at other sites nationwide. The system is designed as a drop-in replacement—it integrates seamlessly with existing infrastructure and eliminates the need for costly modifications.

    “Our hope is that by the end of the first summer season, the results will give us the confidence to move forward with other sites,” Dunbar said during the pitch.

    Additionally, CBRE is not giving up on the idea of an advanced cement project.

    “As an offshoot, NREL pulled us into conversations with several advanced concrete partners about a potential project in 2025,” Dunbar said. “We can continue to pursue the concrete challenge outside of the IN2 program.”

    Intermountain Health’s Strive for Change

    Glen Garrick, system sustainability director for Intermountain Health, is also working with NREL on a project separate from the IN2 pitch he presented. The company has 16 traditional shuttles, and it wants to change that and incorporate advanced technologies.

    Initially, the employee responsible for managing the fleet resisted the idea, uncertain about its feasibility. But the project gained momentum after a visit to NREL.

    “We flew out to NREL and sat in a room talking with 10 experts,” Garrick said. “Some on our team had a healthy skepticism about the shuttles. But after candid discussions with subject matter experts and experienced professionals from NREL, those individuals on our team completely changed their mindset.”

    With approximately 400 clinics and 34 hospitals across the Intermountain West, Intermountain Health plans to order the first set of shuttles in 2025 and begin using them in 2026.

    In addition to the shuttles, Garrick presented a pilot project at one location that would include a solar canopy with panels that move with the sun and battery storage for advanced energy.

    “We tried to find projects that have a long payback because those wouldn’t get approved without IN2,” Garrick said. “It’s not meant to be a huge sexy project—it’s a demonstration project that helps us start to shift toward more on-campus renewables.”

    The driving force is to avoid taking money away from patient care.

    “Every dollar that goes to energy or waste is one less for patient funding,” he said. “Whenever I can bring in external funding, that’s money saved for patient care.”

    During the IN2 pitch day, the attendees networked with each other in between the pitches from the different participants. Photo by Agata Bogucka, NREL

    NREL’s Assistance

    This IN2 cohort did not have to figure out the solutions to their challenges on their own. With guidance from NREL experts and support from consulting firm Overlay Build, participants overcame technical and strategic hurdles unique to their companies to move their projects forward.

    For Coconino County, narrowing down a daunting list of 168 potential HVAC technologies was a critical first step.

    “When I saw the list, first I cried,” Mango-Paget said. “But IN2 and NREL helped us discover the best bang for our buck, and that led us to three companies that could make the biggest impact.”

    NREL’s support did not stop at the planning phase. For CBRE, NREL’s direct involvement in monitoring the Delaware pilot will ensure a smooth transition from concept to implementation.

    “The scientists who helped birth this liquid desiccant technology are going to come help monitor the site in Delaware,” Dunbar said. “That helps de-risk it for us. We’re trying to do this at scale; it’s exciting to be at the front end of that curve.”

    The value of NREL’s expertise also extends beyond IN2’s formal structure. Garrick believes Intermountain’s partnership with NREL will continue independently of the IN2 project.

    “I could see a new project evolving in the next six months,” he said. “We have all the contacts, and I think it’s entirely possible we’ll reach out directly for support.”

    By providing both education now and actionable solutions down the road, NREL and IN2 have empowered these organizations to overcome barriers, adopt innovative technologies, and make measurable progress.

    Winners

    Five of the 10 participants in this first-of-its-kind cohort earned monetary awards.

    • CBRE received $150,000 for its project, which will cover the engineering, design, and construction costs for the pilot and a scalability study.
    • Coconino County received $55,000 for the Rensair and Komfort parts of its project.
    • Digital Realty received $125,000 to partner with Hayzel and improve chilling in its data centers in Santa Clara, California.
    • Galvanize Real Estate received $200,000 to work with EnKoat, an IN2 portfolio company, and Alpen for a pilot on a building in Pedricktown, New Jersey.
    • The University of Colorado Boulder received $220,000 to work with INOVUES to retrofit existing windows in aging buildings with hermetically sealed high-performance glass.

    All the pilot projects must be completed within six months. NREL will keep track of their progress and post updates in the future.

    And the participants—including the five teams that did not earn funding—are walking away with tailored technology adoption playbooks and access to expertise in digitization and change management.

    “Alongside the new relationships formed with NREL, the program itself is an award,” Derdowski said. “We’re already seeing renewed efforts to change the culture at all of these organizations.”

    “I’m really glad we went through the process because we saved one project because of it,” Garrick said. “If it wasn’t for that contact with NREL, that project would have died.”

    Updates on how the installations proceed will be found on www.in2ecosystem.com later this year.

    MIL OSI USA News

  • MIL-OSI Australia: Public comment opens for draft Heritage Management Plan, Mawson’s Huts Historic Site, 2025

    Source: Australian Government – Antarctic Division

    The Department of Climate Change, Energy, the Environment and Water, as manager of the Antarctic site at Cape Denison, has prepared a draft Heritage Management Plan for the Mawson’s Huts Historic Site and is seeking comment on the proposed Mawson’s Huts Historic Site Management Plan 2025.

    Constructed during the Australasian Antarctic Expedition 1911-1914 by Sir Douglas Mawson and his team, Mawson’s Huts Historic Site at Cape Denison is a place of great historical and social significance, and is listed on both the National and Commonwealth Heritage lists.
    In accordance with sections 324S and 341S of the Environment Protection and Biodiversity Conservation Act 1999, the Department invites comment on the Draft Mawson’s Huts Historic Site Heritage Management Plan 2025 from members of the public, key stakeholders, community groups, and Indigenous people with an interest in the place.
    The draft Mawson’s Huts Historic Site Heritage Management Plan 2025 can be viewed online and comments submitted via the Department’s consultation hub at: https://consult.dcceew.gov.au/
    The closing date for public comment is 5:00pm AEDT, on 1 April 2025.
    This content was last updated 4 minutes ago on 28 February 2025.

    MIL OSI News

  • MIL-OSI USA: Senators Marshall and Fischer Introduce the Nationwide Consumer and Fuel Retailer Choice Act of 2025

    US Senate News:

    Source: United States Senator for Kansas Roger Marshall
    Washington, DC – U.S. Senators Roger Marshall, M.D. (R-Kansas) and Deb Fischer (R-Nebraska) introduced the Nationwide Consumer and Fuel Retailer Choice Act of 2025, which would allow the year-round, nationwide sale of E15, a gasoline blend that contains 15% ethanol.
    Increasing the availability of biofuels like E15 would benefit the economy by lowering fuel prices and providing certainty in fuel markets for farmers and consumers. This legislation is the only permanent, nationwide solution to fulfilling President Donald Trump’s mandate for energy independence and rolling back years of burdensome regulations.
    “America’s biofuels industry provides consumers with a carbon-reducing fuel option at the gas pump. This bipartisan legislation ensures E15 can be sold at gas stations year-round and guarantees farmers will continue to make the world cleaner, safer, and better for years to come,” said Senator Marshall. 
    “It’s time to once and for all solidify President Trump’s pledge to allow the sale of year-round E15—giving America’s producers and consumers the certainty they deserve. My bill will put an end to years of patchwork regulations and finally make nationwide, year-round E15 a reality. I look forward to working with my colleagues in the House and the Senate, as well as with President Trump, to get this bill signed into law,” said Senator Fischer.
    Joining Senators Marshall and Fischer are Majority Leader John Thune (R-South Dakota) and Senators Tammy Duckworth (D-Illinois), Shelley Moore Capito (R-West Virginia), Amy Klobuchar (D-Minnesota), Pete Ricketts (R-Nebraska), Dick Durbin (D-Illinois), Jerry Moran (R-Kansas), Chuck Grassley (R-Iowa), Tammy Baldwin (D-Wisconsin), Joni Ernst (R-Iowa), Tina Smith (D-Minnesota), and Mike Rounds (R-South Dakota). 
    U.S. Representatives Adrian Smith (R-Nebraska-03) and Angie Craig (D-Minnesota-02) introduced the companion legislation in the House.
    This legislation is supported by American Petroleum Institute, Renewable Fuels Association, Growth Energy, National Corn Growers Association, National Farmer Union, and National Association of Convenience Stores.
    Click HERE to read the bill text.
    Background:
    Under President Biden, there were restrictions on sales of E15 gasoline in summer months due to alleged environmental concerns.
    Last month, President Trump took steps to make E15 available year-round through his Executive Order Declaring a National Energy Emergency.
    This legislation would make President Trump’s executive order permanent.
    Senator Marshall has been a leader on this issue in the Senate, fighting for the U.S. Treasury Department to restrict the eligibility of the 45Z Tax Credit to renewable fuels made only from domestically sourced feedstocks, like Kansas soybean oil and corn oil.
    Read more about Senator Marshall’s leadership on this issue below:

    MIL OSI USA News

  • MIL-OSI Canada: Budget 2025: Meeting the challenge

    Source: Government of Canada regional news (2)

    MIL OSI Canada News

  • MIL-OSI Security: Ansonia Man Arrested in Stamford Charged with Fentanyl Trafficking Offenses

    Source: Office of United States Attorneys

    Marc H. Silverman, Acting United States Attorney for the District of Connecticut, and Stephen P. Belleau, Acting Special Agent in Charge of the Drug Enforcement Administration for New England, today announced that DAQWON GRAHAM, also known as “Seagull” and “Energy,” 30, of Ansonia, was arrested yesterday on a federal criminal complaint charging him with fentanyl trafficking offenses.

    As alleged in court documents and statements made in court, the Drug Enforcement Administration’s Bridgeport High Intensity Drug Trafficking Area (HIDTA) Task Force and Stamford Police Department identified Graham as a large-scale fentanyl distributor in and around Fairfield County.  Investigators also connected Graham’s drug trafficking activities to an overdose death of a male victim in Branford in March 2023, and an overdose death of a female victim in Shelton in October 2024.  In January and February 2025, investigators made multiple controlled purchases of fentanyl from Graham.

    On February 26, 2025, Graham was arrested on High Ridge Road in Stamford.  It is alleged that Graham possessed approximately 400 grams of fentanyl at the time of his arrest.

    Following his arrest, Graham appeared before U.S. Magistrate Judge S. Dave Vatti in Bridgeport and was ordered detained.

    The complaint charges Graham with possession with intent to distribute 400 grams or more of fentanyl, an offense that carries a mandatory minimum term of imprisonment of five years and a maximum term of imprisonment of 40 years, and with use of a communications device to facilitate a drug trafficking felony, an offense that carries a maximum term of imprisonment of four years.

    Acting U.S. Attorney Silverman stressed that a complaint is only a charge and is not evidence of guilt.  Charges are only allegations, and a defendant is presumed innocent unless and until proven guilty beyond a reasonable doubt.

    This matter is being investigated the Drug Enforcement Administration’s Bridgeport High Intensity Drug Trafficking Area (HIDTA) Task Force.  The Task Force includes personnel from the DEA Bridgeport Resident Office, the Connecticut State Police, and the Bridgeport, Danbury, Norwalk, Stamford, and Stratford Police Departments.  The case is being prosecuted by Assistant U.S. Attorney Lauren C. Clark.

    MIL Security OSI

  • MIL-OSI USA: Murray, Kaptur Follow-Up, Demand Answers from Trump DOE as it Continues to Block Investments to Lower Americans’ Energy Costs

    US Senate News:

    Source: United States Senator for Washington State Patty Murray

    Washington, D.C. — Senator Patty Murray (D-WA), Senate Appropriations Committee Vice Chair and Subcommittee on Energy and Water Development Ranking Member, and Congresswoman Marcy Kaptur (D, OH-09), Ranking Member of the House Appropriations Subcommittee on Energy and Water Development, sent a new letter to Energy Secretary Chris Wright, demanding answers about the Department of Energy’s freeze of key energy investments. Murray and Kaptur pressed Secretary Wright to provide answers to questions they posed in a January 31 letter—responses that DOE has failed to provide—and to expeditiously release illegally blocked funding.

    The Department’s actions continue to cause widespread chaos and confusion, affect a broad array of investments in American communities, and threaten to raise energy costs for American families. We have yet to hear back on any of the questions raised and many of these critical programs remain illegally frozen, write Murray and Kaptur.

    As Secretary, you have a responsibility and duty to execute the laws faithfully,” added Murray and Kaptur. “Congress has enacted laws to invest in America’s security and prosperity and lower American households’ energy costs by addressing our nation’s energy, environmental, and nuclear challenges through transformative science and technology solutions. This administration’s funding freeze continues to create mass uncertainty, will cause energy prices to rise, risks good-paying jobs in communities across the country, and undermines the pursuit of energy dominance.”

    We respectfully ask that you respond to the questions raised in our prior letter and release all of the illegally frozen funds expeditiously,” Murray and Kaptur conclude.

    In their January letter, Murray and Kaptur noted that the illegal freeze of Inflation Reduction Act and Infrastructure Investment and Jobs Act funding is creating unacceptable chaos, confusion, and harm for American families and businesses:

    Stopping these programs is taking money from the pockets of Americans. For example, the Home Energy Rebates programs, funded by the IRA, has been putting money directly back in the hands of American households. The rebates help consumers save money on select home improvement projects that can lower energy bills by providing up to $14,000 per household in rebates. It is estimated that these programs will save households up to $1 billion per year on energy bills and support over 50,000 U.S. jobs. The President’s attempt to freeze the Home Energy Rebates Program means these costs will fall back on American consumers.”

    Full text of the letter is available HERE and below: 

    The Honorable Christopher Wright

    Secretary

    U.S. Department of Energy

    1000 Independence Ave., SW

    Washington, DC 20585

    Dear Secretary Wright:

    We write to follow up on the attached letter sent on January 31, 2025. This letter raised grave concerns about the Department of Energy’s (DOE) unlawful actions to freeze program funding. The Department’s actions continue to cause widespread chaos and confusion, affect a broad array of investments in American communities, and threaten to raise energy costs for American families. We have yet to hear back on any of the questions raised and many of these critical programs remain illegally frozen.

    As Secretary, you have a responsibility and duty to execute the laws faithfully. We reiterate our call for the Department to responsibly carry out duly enacted spending laws, execute its programs, and follow the law as intended for all of its appropriated funding. Congress has enacted laws to invest in America’s security and prosperity and lower American households’ energy costs by addressing our nation’s energy, environmental, and nuclear challenges through transformative science and technology solutions. This administration’s funding freeze continues to create mass uncertainty, will cause energy prices to rise, risks good-paying jobs in communities across the country, and undermines the pursuit of energy dominance.

    We respectfully ask that you respond to the questions raised in our prior letter and release all of the illegally frozen funds expeditiously.

    Sincerely,

    Marcy Kaptur, Ranking Member, Subcommittee on Energy and Water Development, House Committee on Appropriations

    Patty Murray, Ranking Member, Subcommittee on Energy and Water Development, Senate Committee on Appropriations

    MIL OSI USA News

  • MIL-OSI Security: Northwest Arkansas Man Sentenced to More Than Four Years in Prison for Operating an Illegal Money Transmitting Business Using Pandemic Funds

    Source: Federal Bureau of Investigation (FBI) State Crime News

    FAYETTEVILLE – A Northwest Arkansas man was sentenced on February 20, to 51 months in Federal Prison, followed by three years of supervised release. Additionally, he was ordered to pay restitution of $725,558.00 on one count of operating an Illegal Money Transmitting Business. The Honorable Judge Timothy L. Brooks presided over the sentencing hearing, which took place in the United States District Court in Fayetteville.

    According to court documents, Richard Harold Stone, age 77, waived indictment by a grand jury and pleaded guilty to a criminal information charging him with conducting an unlicensed money transmitting business in the State of Arkansas. Stone was the President or Chief Officer of numerous businesses registered with the Arkansas Secretary of State, including: Partex Oman Corp., Renewable Energy Campus Arkansas, Inc., Stonetek Global Corp., and Tires 2 Energy, LLC. Stone also was associated with Environmental Energy & Finance Corp., a Delaware corporation. The advertised purpose of these businesses was developing technology and facilities to repurpose waste materials, such as tires, into useable fuel sources. None of these businesses were registered with the State of Arkansas as a money transmitting business, as required by Arkansas law (Arkansas Code, Section 23-55-806(b)&(c)).

    Between November 2020 and March 2021, Stone received through various bank accounts associated with the above entities and other accounts under his control, deposits of funds from applications made on behalf of unwitting victims for Paycheck Protection Program (PPP) loans, Economic Impact Disaster Loans (EIDL), and Pandemic Unemployment Assistance (PUA), totaling more than $600,000. After receiving these funds, Stone immediately transferred most of the funds by wire transfer to parties in locations including Berne, Switzerland; London, England; New York, NY; Chennai, India; and Mumbai, India.

    At the conclusion of Thursday’s sentencing hearing, Stone was immediately remanded to the custody of the U.S. Marshals Service.

    U.S. Attorney David Clay Fowlkes of the Western District of Arkansas made the announcement.

    The Internal Revenue Service-Criminal Investigation, Federal Bureau of Investigation, and Department of Labor Office of the Inspector General investigated the case.

    Assistant U.S. Attorney Hunter Bridges is prosecuting the case.

    Related court documents may be found on the Public Access to Electronic Records website at www.pacer.gov.

    MIL Security OSI

  • MIL-OSI: Chris Kendall Appointed to Range Resources Board of Directors

    Source: GlobeNewswire (MIL-OSI)

    FORT WORTH, Texas, Feb. 27, 2025 (GLOBE NEWSWIRE) — RANGE RESOURCES CORPORATION (NYSE: RRC) today announced the appointment of Christian S. (Chris) Kendall to its Board of Directors. Mr. Kendall’s appointment is effective February 27 and he will serve on Range’s Governance and Nominating and ESG and Safety Committees.

    Mr. Kendall has more than 30 years of experience in the oil and gas industry, most recently as director, President, and Chief Executive Officer of Denbury Inc. prior to its acquisition by Exxon Mobil Corporation in November 2023.

    Range Chairman, Greg Maxwell, stated, “Chris brings a wealth of technical expertise and a proven record of success as an executive in the energy sector. We are confident Chris’s extensive background in the industry will benefit the Company as we continue strategically developing our extensive Marcellus Shale position and translating that into shareholder value.”

    Prior to joining Denbury, Mr. Kendall was with Noble Energy, serving as the Senior Vice President, Global Operations Services. During his 14-year tenure at Noble Energy, Mr. Kendall held several international and domestic leadership roles. Mr. Kendall began his energy career at Mobil Corporation in 1989.

    Mr. Kendall earned Bachelor of Science in Engineering, Civil Specialty from the Colorado School of Mines and graduated from Harvard Business School’s Advanced Management Program. 

    Mr. Kendall currently serves as a director of NOV Inc. and California Resources Corporation, including its subsidiary, Carbon TerraVault.

    RANGE RESOURCES CORPORATION (NYSE: RRC) is a leading U.S. independent natural gas and NGL producer with operations focused in the Appalachian Basin. The Company is headquartered in Fort Worth, Texas. More information about Range can be found at www.rangeresources.com.

    Range Investor Contact:
    Laith Sando, SVP – Corporate Strategy & Investor Relations
    817-869-4267
    lsando@rangeresources.com

    Range Media Contact:
    Mark Windle, Director of Corporate Communications
    724-873-3223
    mwindle@rangeresources.com

    The MIL Network

  • MIL-OSI: Diversified Closes Summit Natural Resources Acquisition and Tenth Asset Backed Securitization Issuance

    Source: GlobeNewswire (MIL-OSI)

    Bolt-on Acquisition Increases Coal Mine Methane Environmental Credit Cash Flow, Expands Midstream Infrastructure, and Enhances Southern Appalachia Prices

    Strategic Refinance Incorporates 40% Improvement in Cash Flow from New Hedges and an Innovative Master Trust Structure

    Solidifies Diversified as the Leading Issuer of Oil & Gas Securitizations

    BIRMINGHAM, Ala., Feb. 27, 2025 (GLOBE NEWSWIRE) — Diversified Energy Company PLC (LSE:DEC; NYSE:DEC) (“Diversified” or the “Company”) announces the close of its previously announced acquisition of operated natural gas properties and related midstream pipeline infrastructure located within Virginia, West Virginia, and Alabama (the “Assets”) from Summit Natural Resources (the “Seller”) (together with the assets, the “Acquisition”).

    Additionally, the Company closed on an asset backed securitization (“ABS”) refinancing, creating the ABS X note. Diversified will use the proceeds from the ABS transaction to consolidate and repay the outstanding principal of the previously issued ABS I, ABS II and Term Loan I, utilizing those assets plus additional Summit Natural Resources assets as collateral in the new structure. The ABS transaction will also benefit from an improved hedging profile, creating enhanced margins and cash flows. Additional proceeds from this refinancing will be used to reduce outstanding borrowings and for general corporate purposes.

    Acquisition Highlights

    • Acquisition net purchase price of ~$42 million
    • Current net production of ~12 MMcfepd (2 Mboepd)(a)
    • PDP Reserves of 65 Bcfe (11 MMBoe) with PV-10 of ~$55 million(b)
      • Purchase price equivalent of ~PV-16(b)
    • Estimated 2025 Adjusted EBITDA of ~$12 million(b)(c)
    • Existing Coal Mine Methane (“CMM”) volumes with opportunities to extend future production and additional environmental credits
    • Appalachian assets overlap existing operations providing synergies for increased cash margins
    • Strategic midstream pipeline assets facilitate capability to enhance commodity realizations
    • Recent improvements to commodity prices have further-enhanced the transaction economics

    ABS Issuance Highlights

    • $530 million ABS X note structured as a master trust
    • Strategic hedges expected to add ~40% ($38 million) to EBITDA(c) of refinanced assets
    • Significantly oversubscribed (6.5x) with orders from 20 unique investors, reflecting the cash flow quality of our assets and Diversified’s reputation as a responsible issuer
    • Investment grade rated notes with blended fixed coupon of approximately 6.4% in A tranche
    • Improved amortization expected to generate increased cash flows

    Sustainability-Linked

    Sustainable Fitch has again-provided a Second Party Opinion that the instrument’s Key Performance Indicators (the “KPIs”) align with the International Capital Markets Association (ICMA) framework for sustainability-linked bond principles, highlighting Diversified’s commitment to aligning its financing with the Company’s overall sustainability strategy.

    *ratings established by Fitch Ratings,Inc.

    Commenting on the Acquisition and ABS transaction, CEO Rusty Hutson, Jr. said:

    “We are excited to announce the completion of another acquisition of high-quality, bolt-on assets that are uniquely positioned to benefit from the operational expertise of our field teams, capture higher prices with exposure to premium Transco Zone 5 pricing, and are poised to provide additional revenues from the sale of incremental environmental credits with our growth in the production of coal mine methane. We continue to believe there is a sizeable backlog of organic Coal Mine Methane cash flow growth within our current Appalachian portfolio, and this acquisition highlights our ability to leverage existing capabilities, assets, and intellectual capital to grow this segment of our revenue stream.

    Brad Gray, CFO further commented:

    Supported by a growing base of loyal credit investors, we are now a seasoned programmatic issuer, and this ABS transaction achieved record demand with a significant amount of interest from a large group of new participants. This strategic refinance improves asset level cash flow with higher hedge prices and a more refined amortization schedule. Our increasing operational scale, track record of stable asset performance, and strength of our business enable us to attract reliable sources of capital and achieve a lower overall cost of capital. This outcome is a testament to how the financial markets value Diversified’s reliable production and consistent cash flows.”

    On the Securitization: Barclays Capital, Inc. acted as Sole Structuring Advisor and Placement Agent, Mizuho Securities USA LLC, KeyBanc Capital Markets Inc., and Legado Capital Advisors, LLC acted as Co-Placement Agents.

    Detring Energy Advisors acted as the sell side advisor to Summit Natural Resources.

    Footnotes:

    (a)   Current production based on estimated average daily production for January 2025; Estimate based on historical performance and engineered type curves for the Assets.
         
    (b)   Based on engineering reserves assumptions using historical cost assumptions and NYMEX strip as of October 28, 2024 for the twelve months ended December 31, 2025.
         
    (c)   Adjusted EBITDA is a Non-IFRS measure. As presented for the ABS transaction, represents the twelve months ended February 28, 2026. for more information, see “Use of Non-IFRS Measures”.
         

    For Company-specific items, refer also to the Glossary of Terms and/or Alternative Performance Measures found in the Company’s 2024 Interim Report dated June 30, 2024 and Form 20-F for the year ended December 31, 2023 filed with the United States Securities and Exchange Commission.

    For further information, please contact:

    Diversified Energy Company PLC +1 973 856 2757
    Doug Kris dkris@dgoc.com
    Senior Vice President, Investor Relations & Corporate Communications www.div.energy
       
    FTI Consulting dec@fticonsulting.com
    U.S. & UK Financial Public Relations  
       

    About Diversified Energy Company PLC

    Diversified is a leading publicly traded energy company focused on natural gas and liquids production, transport, marketing, and well retirement. Through our unique and differentiated strategy, we acquire existing, long-life assets and invest in them to improve environmental and operational performance until retiring those assets in a safe and environmentally secure manner. Recognized by ratings agencies and organizations for our sustainability leadership, this solutions-oriented, stewardship approach makes Diversified the Right Company at the Right Time to responsibly produce energy, deliver reliable free cash flow, and generate shareholder value.

    Forward-Looking Statements

    This announcement contains forward-looking statements (within the meaning of the U.S. Private Securities Litigation Reform Act of 1995). These forward-looking statements, which contain the words “anticipate”, “believe”, “intend”, “estimate”, “expect”, “may”, “will”, “seek”, “continue”, “aim”, “target”, “projected”, “plan”, “goal”, “achieve”, “opportunity” and words of similar meaning, reflect the Company’s beliefs and expectations and are based on numerous assumptions regarding the Company’s present and future business strategies and the environment the Company will operate in and are subject to risks and uncertainties that may cause actual results to differ materially. No representation is made that any of these statements or forecasts will come to pass or that any forecast results will be achieved. Expected benefits of the Acquisition and the ABS transaction, including the impact of the Acquisition and the ABS transaction on the company’s cash flows and cash margins, and the Company’s production of coal mine methane, may not be realized. Forward-looking statements involve inherent known and unknown risks, uncertainties and contingencies because they relate to events and depend on circumstances that may or may not occur in the future and may cause the actual results, performance or achievements of the Company to be materially different from those expressed or implied by such forward-looking statements. Many of these risks and uncertainties relate to factors that are beyond the Company’s ability to control or estimate precisely, including the risk factors described in the “Risk Factors” section in the Company’s Annual Report and Form 20-F for the year ended December 31, 2023 and the risk factors described in Exhibit 99.2 to the Company’s Form 6-K furnished with the SEC on January 27, 2025, in each case filed with the United States Securities and Exchange Commission. Forward-looking statements speak only as of their date and neither the Company nor any of its directors, officers, employees, agents, affiliates or advisers expressly disclaim any obligation to supplement, amend, update or revise any of the forward-looking statements made herein, except where it would be required to do so under applicable law. As a result, you are cautioned not to place undue reliance on such forward-looking statements.

    Use of Non-IFRS Measures

    Certain key operating metrics that are not defined under IFRS (alternative performance measures) are included in this announcement. These non-IFRS measures are used by us to monitor the underlying business performance of the Company from period to period and to facilitate comparison with our peers. Since not all companies calculate these or other non-IFRS metrics in the same way, the manner in which we have chosen to calculate the non-IFRS metrics presented herein may not be compatible with similarly defined terms used by other companies. The non-IFRS metrics should not be considered in isolation of, or viewed as substitutes for, the financial information prepared in accordance with IFRS. Certain of the key operating metrics are based on information derived from our regularly maintained records and accounting and operating systems.

    Adjusted EBITDA

    As used herein, EBITDA represents earnings before interest, taxes, depletion, depreciation and amortization. Adjusted EBITDA includes adjusting for items that are not comparable period-over-period, namely, accretion of asset retirement obligation, other (income) expense, loss on joint and working interest owners receivable, (gain) loss on bargain purchases, (gain) loss on fair value adjustments of unsettled financial instruments, (gain) loss on natural gas and oil property and equipment, costs associated with acquisitions, other adjusting costs, non-cash equity compensation, (gain) loss on foreign currency hedge, net (gain) loss on interest rate swaps and items of a similar nature.

    EBITDA and Adjusted EBITDA should not be considered in isolation or as a substitute for operating profit or loss, net income or loss, or cash flows provided by operating, investing, and financing activities. However, we believe such measures are is useful to an investor in evaluating our financial performance because they (1) are widely used by investors in the natural gas and oil industry as an indicator of underlying business performance; (2) help investors to more meaningfully evaluate and compare the results of our operations from period to period by removing the often-volatile revenue impact of changes in the fair value of derivative instruments prior to settlement; (3) with respect to Adjusted EBITDA, is used in the calculation of a key metric in one of our Credit Facility financial covenants; and (4) are used by us as a performance measure in determining executive compensation. We are unable to provide a quantitative reconciliation of forward-looking EBITDA and Adjusted EBITDA to the most directly comparable forward-looking IFRS measures because the items necessary to estimate such forward-looking IFRS measures are not accessible or estimable at this time without unreasonable efforts. The reconciling items in future periods could be significant.

    PV-10

    PV-10 is a non-IFRS financial measure and generally differs from Standardized Measure, the most directly comparable IFRS measure, because it does not include the effects of income taxes on future net cash flows. While the Standardized Measure is free cash dependent on the unique tax situation of each company, PV-10 is based on a pricing methodology and discount factors that are consistent for all companies. In this announcement, PV-10 is calculated using NYMEX pricing. It is not practicable to reconcile PV-10 using NYMEX pricing to standardized measure in accordance with IFRS at this time. Investors should be cautioned that neither PV-10 nor the Standardized Measure represents an estimate of the fair market value of proved reserves.

    The MIL Network

  • MIL-OSI: Sunrun Reports Fourth Quarter and Full Year 2024 Financial Results

    Source: GlobeNewswire (MIL-OSI)

    Cash Generation of $34 million in Q4 after safe harbor equipment purchases, third consecutive quarter of positive Cash Generation

    Paid down $132 million of recourse debt in Q4 with excess cash

    Cash Generation guidance of $200 million to $500 million in 2025

    Cash Generation guidance of $40 to $50 million in Q1

    Net Earning Assets increased to $6.8 billion, including $947 million of Total Cash

    Storage Capacity Installed of 392 Megawatt hours in Q4, exceeding high-end of guidance range and representing 78% year-over-year growth, as storage attachment rates reach 62%

    Solar Energy Capacity Installed of 242 Megawatts in Q4, within the guidance range, reaching 7.5 Gigawatts of Networked Solar Energy Capacity

    SAN FRANCISCO, Feb. 27, 2025 (GLOBE NEWSWIRE) — Sunrun (Nasdaq: RUN), the nation’s leading provider of clean energy as a subscription service, today announced financial results for the fourth quarter and full year ended December 31, 2024.

    “We are growing, generating meaningful cash, increasing our book value of deployed systems, and paying down debt. We are poised to further improve our operating and financial results, and deliver a very strong 2025 with meaningful Cash Generation. Our actions to optimize our product mix, prioritize the highest value geographies and routes to market and an intense focus on cost as we grow have resulted in the highest Net Subscriber Values Sunrun has ever reported,” said Mary Powell, Sunrun’s Chief Executive Officer. “We are improving in every dimension we control – focusing on fast, effective execution, delivering strong financial and operating results, gaining share in a disciplined way, while building a long-term foundation of valuable grid resources.”

    “In the fourth quarter, we again set new margin records and delivered the third consecutive quarter of Cash Generation. We continue to execute well in the capital markets, raising more than $4 billion in asset-level debt and tax equity financing during 2024, and more than $800 million in non-recourse debt financing year-to-date. We have extended our runway of tax equity commitments and term sheets, including $1.3 billion added year-to-date,” said Danny Abajian, Sunrun’s Chief Financial Officer. “We have a strong balance sheet with no near-term corporate debt maturities and have paid down recourse parent debt by $186 million since March, including a $132 million paydown using excess cash in Q4. As we increase our Cash Generation, we will continue to further pay down parent recourse debt and are committed to a capital allocation strategy beyond this initial de-leveraging period that drives significant shareholder value.”

    Fourth Quarter Updates

    • Storage Attachment Rates Reach 62%: Customer Additions with storage grew more than 50% during the quarter compared to the prior-year period. Storage attachment rates on installations reached 62% in Q4, up from 45% in the prior-year period, with 392 Megawatt hours installed during the quarter. Sunrun has installed more than 156,000 solar and storage systems, representing over 2.5 Gigawatt hours of stored energy capacity.
    • Continued Strong Capital Markets Execution: In January 2025, Sunrun priced a $629 million securitization of residential solar and battery systems. The securitization is Sunrun’s thirteenth securitization since 2015 and first issuance in 2025. The oversubscribed transaction was structured with three separate classes of A rated notes, only two of which were publicly offered. The weighted average spread of the notes was 197 basis points, which was an improvement of approximately 38 basis points from our prior securitization in September. Similar to prior transactions, Sunrun raised additional capital in a subordinated non-recourse financing, which increased the cumulative advance rate to above 80% as measured against the initial Contracted Subscriber Value of the portfolio.
    • Paying Down Recourse Debt: We continue to pay down parent recourse debt. During the fourth quarter, we repurchased $125.5 million in principal of our 2026 Convertible Notes. As of December 31, 2024 we had only $7.7 million outstanding of these notes, which we may repurchase in 2025. Since March 31, 2024 we have paid down recourse debt by $186 million, by repurchasing our 2026 Convertible Notes and reducing borrowings under our recourse Working Capital Facility. We have also increased our Total Cash balance by $164 million and grown Net Earning Assets by $1.5 billion. We expect to further pay down our recourse debt in 2025 by $100 million or more. Aside from the $7.7 million outstanding of our 2026 Convertible Notes, we have no recourse debt maturities until March 2027. Over time we will explore further capital allocation options to maximize shareholder value, based on market conditions and our long-term outlook.
    • Improving Grid Stability with Virtual Power Plants: During 2024, Sunrun’s virtual power plants (VPPs) successfully supported power grids across the country with a combined instantaneous peak of nearly 80 megawatts—a capacity greater than many traditional fossil-fuel power plants. These innovative programs leveraged Sunrun’s fleet of residential solar and battery systems—the largest in America—empowering customers to generate, store, and share their own solar energy. In 2024, more than 20,000 Sunrun customers participated in 16 virtual power plant programs across nine states and territories. From California and Texas to Puerto Rico and New England, the customers’ batteries supplied on-demand, stored solar energy to augment power resources during hundreds of critical energy events.

    Key Operating Metrics

    In the fourth quarter of 2024, Customer Additions were 32,932 including 30,709 Subscriber Additions. As of December 31, 2024, Sunrun had 1,048,842 Customers, including 889,186 Subscribers. Customers grew 12% in the fourth quarter of 2024 compared to the fourth quarter of 2023.

    Annual Recurring Revenue from Subscribers was approximately $1.6 billion as of December 31, 2024. The Average Contract Life Remaining of Subscribers was 17.6 years as of December 31, 2024.

    Subscriber Value was $55,811 in the fourth quarter of 2024, a 11% increase compared to the fourth quarter of 2023. Creation Cost was $36,634 in the fourth quarter of 2024, a 1% decrease compared to the fourth quarter of 2023.

    Net Subscriber Value was $19,177 in the fourth quarter of 2024. Total Value Generated was $589 million in the fourth quarter of 2024. On a pro-forma basis assuming a 7.3% discount rate, consistent with capital costs observed in the quarter, Subscriber Value was $50,998 and Net Subscriber Value was $14,364 in the fourth quarter of 2024.

    Gross Earning Assets as of December 31, 2024, were $17.8 billion. Net Earning Assets were $6.8 billion, which included $947 million in Total Cash, as of December 31, 2024.

    Cash Generation was $34.2 million in the fourth quarter of 2024, the third consecutive quarter of positive Cash Generation.

    Storage Capacity Installed was 392.0 Megawatt hours in the fourth quarter of 2024, a 78% increase compared to the fourth quarter of 2023.

    Solar Energy Capacity Installed was 242.4 Megawatts in the fourth quarter of 2024, a 7% increase compared to the fourth quarter of 2023. Included in this figure is 232.0 Megawatts of Solar Energy Capacity Installed for Subscribers in the fourth quarter of 2024, an 11% increase compared to the fourth quarter of 2023.

    Networked Solar Energy Capacity was 7,531 Megawatts as of December 31, 2024. Included in this figure is 6,436 Megawatts of Networked Solar Energy Capacity for Subscribers as of December 31, 2024.

    Networked Storage Capacity was 2.5 Gigawatt hours as of December 31, 2024.

    The solar energy systems we deployed in Q4 are expected to offset the emission of 4.8 million metric tons of CO2 over the next thirty years. Over the last twelve months ended December 31, 2024, Sunrun’s systems are estimated to have offset 4.0 million metric tons of CO2.

    Outlook

    Cash Generation is expected to be in a range of $40 million to $50 million in the first quarter of 2025.

    For the full-year 2025, Cash Generation is expected to be in a range of $200 million to $500 million.

    Storage Capacity Installed is expected to be in a range of 265 to 275 Megawatt hours in the first quarter of 2025, representing approximately 30% growth year over year at the midpoint.

    Solar Energy Capacity Installed is expected to be in a range of 170 to 180 Megawatts in the first quarter of 2025, representing approximately flat year over year growth at the midpoint.

    For the full-year 2025, the Company expects robust growth in Storage Capacity Installed year over year, and Solar Energy Capacity Installed is expected to be approximately flat year over year.

    Fourth Quarter 2024 GAAP Results

    Total revenue was $518.5 million in the fourth quarter of 2024, up $1.9 million, or 0%, from the fourth quarter of 2023. Customer agreements and incentives revenue was $388.6 million, an increase of $67.0 million, or 21%, compared to the fourth quarter of 2023. Solar energy systems and product sales revenue was $129.9 million, a decrease of $65.1 million, or 33%, compared to the fourth quarter of 2023. The increasing mix of Subscribers results in less upfront revenue recognition, as revenue is recognized over the life of the Customer Agreement, which is typically 20 or 25 years.

    Total cost of revenue was $421.0 million, a decrease of 13% year-over-year. Total operating expenses were $652.6 million, a decrease of 9% year-over-year, on a pro-forma basis to exclude a non-cash goodwill impairment, which was incurred in the fourth quarter of 2024.

    Net loss attributable to common stockholders was $2,813.7 million, or $12.51 per basic and diluted share for the fourth quarter of 2024. Pro forma to exclude non-cash impairment charges, results in non-GAAP net income of $360.9 million or $1.41 per diluted share for the fourth quarter of 2024.

    Full Year 2024 GAAP Results

    Total revenue was $2,037.7 million in the full year 2024, down $222.1 million, or 10%, from the full year 2023. Customer agreements and incentives revenue was $1,505.2 million, an increase of $318.5 million, or 27%, compared to the full year 2023. Solar energy systems and product sales revenue was $532.5 million, a decrease of $540.6 million, or 50%, compared to the full year 2023.

    Total cost of revenue was $1,709.2 million, a decrease of 18% year-over-year. Total operating expenses were $2,610.8 million, a decrease of 15% year-over year, on a pro-forma basis to exclude non-cash goodwill impairment, which was incurred in both the full year 2023 and full year 2024.

    During the year, Sunrun recorded a non-cash goodwill impairment charge of approximately $3.1 billion. Due to the decline in our stock price, we wrote down our goodwill balance of $3.1 billion in its entirety during the fourth quarter of 2024. The goodwill primarily arose following the stock-for-stock acquisition of Vivint Solar in October 2020, with the majority arising from and determined based on the market capitalizations at the time of the acquisition. The Company recorded a non-cash goodwill impairment charge of $3.1 billion, or $14.05 per basic share, in our Consolidated Statement of Operations for the full year 2024, which was reflected in the Company’s fourth quarter results.

    Net loss attributable to common stockholders was $2,846.2 million, or $12.81 per basic and diluted share for the full year 2024. Pro-forma to exclude non-cash impairment charges, results in non-GAAP net income of $333.7 million or $1.33 per diluted share for the full-year 2024.

    Financing Activities

    As of February 27, 2025, closed transactions and executed term sheets provide us with expected tax equity to fund over 500 Megawatts of Solar Energy Capacity Installed for Subscribers beyond what was deployed through December 31, 2024. Sunrun also has $680 million in unused commitments available in its non-recourse senior revolving warehouse loan after the January securitization, to fund approximately 230 megawatts of projects for Subscribers.

    Conference Call Information

    Sunrun is hosting a conference call for analysts and investors to discuss its fourth quarter and full year 2024 results and business outlook at 1:30 p.m. Pacific Time today, February 27, 2025. A live audio webcast of the conference call along with supplemental financial information will be accessible via the “Investor Relations” section of Sunrun’s website at https://investors.sunrun.com. The conference call can also be accessed live over the phone by dialing (877) 407-5989 (toll free) or (201) 689-8434 (toll). An audio replay will be available following the call on the Sunrun Investor Relations website for approximately one month.

    About Sunrun

    Sunrun Inc. (Nasdaq: RUN) revolutionized the solar industry in 2007 by removing financial barriers and democratizing access to locally-generated, renewable energy. Today, Sunrun is the nation’s leading provider of clean energy as a subscription service, offering residential solar and storage with no upfront costs. Sunrun’s innovative products and solutions can connect homes to the cleanest energy on earth, providing them with energy security, predictability, and peace of mind. Sunrun also manages energy services that benefit communities, utilities, and the electric grid while enhancing customer value. Discover more at www.sunrun.com

    Non-GAAP Information

    This press release includes references to certain non-GAAP financial measures, such as non-GAAP net (loss) income and non-GAAP net (loss) income per share. We believe that these non-GAAP financial measures, when reviewed in conjunction with GAAP financial measures, can provide meaningful supplemental information for investors regarding the performance of our business and facilitate a meaningful evaluation of current period performance on a comparable basis with prior periods. Our management uses these non-GAAP financial measures in order to have comparable financial results to analyze changes in our underlying business from quarter to quarter. These non-GAAP financial measures should be considered as a supplement to, and not as a substitute for or superior to the GAAP financial measures presented in this press release and our financial statements and other publicly filed reports. Non-GAAP measures as presented herein may not be comparable to similarly titled measures used by other companies.

    Non-GAAP net (loss) income is defined as GAAP net (loss) income adjusted by the non-cash goodwill impairment charge, non-cash adjustment to equity investments, and the debt discount amortization. Management believes the exclusion of this non-cash and non-recurring item provides useful supplemental information to investors and facilitates the analysis of its operating results and comparison of operating results across reporting periods.

    Forward Looking Statements

    This communication contains forward-looking statements related to Sunrun (the “Company”) within the meaning of Section 27A of the Securities Act of 1933, and Section 21E of the Securities Exchange Act of 1934 and the Private Securities Litigation Reform Act of 1995. Such forward-looking statements include, but are not limited to, statements related to: the Company’s financial and operating guidance and expectations; the Company’s business plan, trajectory, expectations, market leadership, competitive advantages, operational and financial results and metrics (and the assumptions related to the calculation of such metrics); the Company’s momentum in its business strategies including expectations regarding market share, total addressable market, growth in certain geographies, customer value proposition, market penetration, growth of certain divisions, financing activities, financing capacity, product mix, and ability to manage cash flow and liquidity; the growth of the solar industry; the Company’s financing activities and expectations to refinance, amend, and/or extend any financing facilities; trends or potential trends within the solar industry, our business, customer base, and market; the Company’s ability to derive value from the anticipated benefits of partnerships, new technologies, and pilot programs, including contract renewal and repowering programs; anticipated demand, market acceptance, and market adoption of the Company’s offerings, including new products, services, and technologies; the Company’s strategy to be a margin-focused, multi-product, customer-oriented company; the ability to increase margins based on a shift in product focus; expectations regarding the growth of home electrification, electric vehicles, virtual power plants, and distributed energy resources; the Company’s ability to manage suppliers, inventory, and workforce; supply chains and regulatory impacts affecting supply chains; the Company’s leadership team and talent development; the legislative and regulatory environment of the solar industry and the potential impacts of proposed, amended, and newly adopted legislation and regulation on the solar industry and our business; the ongoing expectations regarding the Company’s storage and energy services businesses and anticipated emissions reductions due to utilization of the Company’s solar energy systems; and factors outside of the Company’s control such as macroeconomic trends, bank failures, public health emergencies, natural disasters, acts of war, terrorism, geopolitical conflict, or armed conflict / invasion, and the impacts of climate change. These statements are not guarantees of future performance; they reflect the Company’s current views with respect to future events and are based on assumptions and estimates and are subject to known and unknown risks, uncertainties and other factors that may cause actual results, performance or achievements to be materially different from expectations or results projected or implied by forward-looking statements. The risks and uncertainties that could cause the Company’s results to differ materially from those expressed or implied by such forward-looking statements include: the Company’s continued ability to manage costs and compete effectively; the availability of additional financing on acceptable terms; worldwide economic conditions, including slow or negative growth rates and inflation; volatile or rising interest rates; changes in policies and regulations, including net metering, interconnection limits, and fixed fees, or caps and licensing restrictions and the impact of these changes on the solar industry and our business; the Company’s ability to attract and retain the Company’s business partners; supply chain risks and associated costs; realizing the anticipated benefits of past or future investments, partnerships, strategic transactions, or acquisitions, and integrating those acquisitions; the Company’s leadership team and ability to attract and retain key employees; changes in the retail prices of traditional utility generated electricity; the availability of rebates, tax credits and other incentives; the availability of solar panels, batteries, and other components and raw materials; the Company’s business plan and the Company’s ability to effectively manage the Company’s growth and labor constraints; the Company’s ability to meet the covenants in the Company’s investment funds and debt facilities; factors impacting the home electrification and solar industry generally, and such other risks and uncertainties identified in the reports that we file with the U.S. Securities and Exchange Commission from time to time. All forward-looking statements used herein are based on information available to us as of the date hereof, and we assume no obligation to update publicly these forward-looking statements for any reason, except as required by law.

    Citations to industry and market statistics used herein may be found in our Investor Presentation, available via the “Investor Relations” section of Sunrun’s website at https://investors.sunrun.com.

    Consolidated Balance Sheets
    (In Thousands)
        As of December 31,
          2024     2023
    Assets        
    Current assets:        
    Cash   $ 574,956   $ 678,821
    Restricted cash     372,312     308,869
    Accounts receivable, net     170,706     172,001
    Inventories     402,083     459,746
    Prepaid expenses and other current assets     202,579     262,822
    Total current assets     1,722,636     1,882,259
    Restricted cash     148     148
    Solar energy systems, net     15,032,115     13,028,871
    Property and equipment, net     121,239     149,139
    Goodwill         3,122,168
    Other assets     3,021,746     2,267,652
    Total assets   $ 19,897,884   $ 20,450,237
    Liabilities and total equity        
    Current liabilities:        
    Accounts payable   $ 354,214   $ 230,723
    Distributions payable to noncontrolling interests and redeemable noncontrolling interests     41,464     35,180
    Accrued expenses and other liabilities     543,752     499,225
    Deferred revenue, current portion     129,442     128,600
    Deferred grants, current portion     7,900     8,199
    Finance lease obligations, current portion     26,045     22,053
    Non-recourse debt, current portion     231,665     547,870
    Pass-through financing obligation, current portion         16,309
    Total current liabilities     1,334,482     1,488,159
    Deferred revenue, net of current portion     1,208,905     1,067,461
    Deferred grants, net of current portion     196,535     195,724
    Finance lease obligations, net of current portion     66,139     68,753
    Line of credit     384,226     539,502
    Non-recourse debt, net of current portion     11,806,181     9,191,689
    Convertible senior notes     479,420     392,867
    Pass-through financing obligation, net of current portion         278,333
    Other liabilities     119,846     190,866
    Deferred tax liabilities     137,940     122,870
    Total liabilities     15,733,674     13,536,224
    Redeemable noncontrolling interests     624,159     676,177
    Total stockholders’ equity     2,554,207     5,230,228
    Noncontrolling interests     985,844     1,007,608
    Total equity     3,540,051     6,237,836
    Total liabilities, redeemable noncontrolling interests and total equity   $ 19,897,884   $ 20,450,237
    Consolidated Statements of Operations
    (In Thousands, Except Per Share Amounts)

        Three Months Ended
    December 31,
      Year Ended
    December 31,
          2024       2023       2024       2023  
    Revenue:                
    Customer agreements and incentives   $ 388,574     $ 321,555     $ 1,505,227     $ 1,186,706  
    Solar energy systems and product sales     129,918       195,035       532,492       1,073,107  
    Total revenue     518,492       516,590       2,037,719       2,259,813  
    Operating expenses:                
    Cost of customer agreements and incentives     292,632       287,780       1,169,213       1,077,114  
    Cost of solar energy systems and product sales     128,361       194,808       539,952       1,019,638  
    Sales and marketing     150,751       166,760       617,162       740,821  
    Research and development     8,794       7,663       39,304       21,816  
    General and administrative     72,045       57,110       245,127       221,067  
    Goodwill Impairment     3,122,168             3,122,168       1,158,000  
    Total operating expenses     3,774,751       714,121       5,732,926       4,238,456  
    Loss from operations     (3,256,259 )     (197,531 )     (3,695,207 )     (1,978,643 )
    Interest expense, net     (233,385 )     (181,826 )     (848,366 )     (652,989 )
    Other income (expense), net     89,829       (157,644 )     161,539       (63,900 )
    Loss before income taxes     (3,399,815 )     (537,001 )     (4,382,034 )     (2,695,532 )
    Income tax benefit     136       (1,595 )     (26,817 )     (12,691 )
    Net loss     (3,399,951 )     (535,406 )     (4,355,217 )     (2,682,841 )
    Net loss attributable to noncontrolling interests and redeemable noncontrolling interests     (586,294 )     (185,282 )     (1,509,050 )     (1,078,344 )
    Net loss attributable to common stockholders   $ (2,813,657 )   $ (350,124 )   $ (2,846,167 )   $ (1,604,497 )
    Net loss per share attributable to common stockholders                
    Basic   $ (12.51 )   $ (1.60 )   $ (12.81 )   $ (7.41 )
    Diluted   $ (12.51 )   $ (1.60 )   $ (12.81 )   $ (7.41 )
    Weighted average shares used to compute net loss per share attributable to common stockholders                
    Basic     224,896       218,461       222,215       216,642  
    Diluted     224,896       218,461       222,215       216,642  
    Consolidated Statements of Cash Flows
    (In Thousands)

        Three Months Ended December 31,   Year Ended December 31,
          2024       2023       2024       2023  
    Operating activities:                
    Net loss   $ (3,399,951 )   $ (535,406 )   $ (4,355,217 )   $ (2,682,841 )
    Adjustments to reconcile net loss to net cash used in operating activities:                
    Depreciation and amortization, net of amortization of deferred grants     162,343       143,024       620,876       531,669  
    Goodwill impairment     3,122,168             3,122,168       1,158,000  
    Deferred income taxes     136       (1,623 )     (26,817 )     (12,716 )
    Stock-based compensation expense     28,869       27,555       112,825       111,781  
    Interest on pass-through financing obligations           4,862       8,837       19,504  
    Reduction in pass-through financing obligations           (9,820 )     (20,787 )     (40,352 )
    Unrealized (gain) loss on derivatives     (122,319 )     108,226       (120,008 )     28,105  
    Other noncash items     105,220       118,956       210,479       261,390  
    Changes in operating assets and liabilities:                
    Accounts receivable     5,741       5,762       (14,974 )     15,748  
    Inventories     (59,735 )     202,055       57,663       324,158  
    Prepaid expenses and other current assets     (301,380 )     (142,438 )     (771,997 )     (476,628 )
    Accounts payable     141,070       (52,514 )     177,449       (108,785 )
    Accrued expenses and other liabilities     4,182       (31,986 )     80,588       (56,473 )
    Deferred revenue     55,297       47,340       152,762       106,700  
    Net cash used in operating activities     (258,359 )     (116,007 )     (766,153 )     (820,740 )
    Investing activities:                
    Payments for the costs of solar energy systems     (791,785 )     (651,462 )     (2,699,452 )     (2,587,183 )
    Purchase of equity investment           (5,000 )           (5,000 )
    Purchases of property and equipment, net     (627 )     (4,662 )     (1,572 )     (20,960 )
    Net cash provided by (used in) investing activities     (792,412 )     (661,124 )     (2,701,024 )     (2,613,143 )
    Financing activities:                
    Proceeds from state tax credits, net of recapture                 5,203       4,033  
    Proceeds from trade receivable financing     124,261       41,225       124,261       41,225  
    Repayment of trade receivable financing           (41,225 )           (41,225 )
    Proceeds from line of credit     48,700       473,277       354,256       1,124,675  
    Repayment of line of credit     (56,998 )     (451,023 )     (509,532 )     (1,090,331 )
    Proceeds from issuance of convertible senior notes, net of capped call transaction                 444,822        
    Repurchase of convertible senior notes     (117,235 )     (1,545 )     (346,581 )     (1,545 )
    Proceeds from issuance of non-recourse debt     644,950       556,100       4,009,906       3,745,580  
    Repayment of non-recourse debt     (102,748 )     (175,728 )     (1,794,962 )     (1,575,527 )
    Payment of debt fees     (128 )     (412 )     (93,875 )     (47,342 )
    Proceeds from pass-through financing and other obligations, net           2,100       4,795       8,812  
    Repayment of pass-through financing obligation                 (240,288 )      
    Payment of finance lease obligations     (6,605 )     (6,484 )     (27,240 )     (23,279 )
    Contributions received from noncontrolling interests and redeemable noncontrolling interests     521,480       459,858       1,811,966       1,572,399  
    Distributions paid to noncontrolling interests and redeemable noncontrolling interests     (70,269 )     (51,578 )     (308,657 )     (225,114 )
    Acquisition of noncontrolling interest     (4,761 )           (26,195 )     (46,274 )
    Proceeds from transfer of investment tax credits     148,586       6,980       705,697       6,980  
    Payments to redeemable noncontrolling interests and noncontrolling interests of investment tax credits     (148,586 )     (6,980 )     (705,697 )     (6,980 )
    Net proceeds related to stock-based award activities     6,923       8,459       18,876       22,611  
    Net cash provided by financing activities     987,570       813,024       3,426,755       3,468,698  
    Net change in cash and restricted cash     (63,201 )     35,893       (40,422 )     34,815  
    Cash and restricted cash, beginning of period     1,010,617       951,945       987,838       953,023  
    Cash and restricted cash, end of period   $ 947,416     $ 987,838     $ 947,416     $ 987,838  
    Reconciliation between GAAP and Non-GAAP diluted (loss) income per share:

        Three Months Ended
    December 31, 2024
      Year Ended
    December 31, 2024
        Net (Loss)
    Income
      Diluted EPS   Net (Loss)
    Income
      Diluted EPS
    GAAP diluted loss per share   $ (2,813,657 )   $ (12.51 )   $ (2,846,167 )   $ (12.81 )
    Debt Discount Amortization     1,131       0.01       6,438       0.03  
    Non-cash impairment charges (2)     3,173,450       14.11       3,173,450       14.28  
    Non-GAAP diluted income per share (1)   $ 360,924     $ 1.41     $ 333,721     $ 1.33  
                     
    GAAP weighted average shares for diluted EPS     224,896           222,215      
    Non-GAAP weighted average shares for diluted EPS     256,614           250,622      


    (1)
       Non-GAAP diluted income per share excludes the effects of the pro forma adjustment detailed above. Non- GAAP diluted income per share is adjusted to exclude this item, as it is not used by management to evaluate the performance of the business.
    (2)   Excluding this item of non-recurring, infrequent or unusual nature and its impact on the comparability of our results for the period to prior periods and future expected trends.

    Key Operating and Financial Metrics

    The following operating metrics are used by management to evaluate the performance of the business. Management believes these metrics, when taken together with other information contained in our filings with the SEC and within this press release, provide investors with helpful information to determine the economic performance of the business activities in a period that would otherwise not be observable from historic GAAP measures. Management believes that it is helpful to investors to evaluate the present value of cash flows expected from subscribers over the full expected relationship with such subscribers (“Subscriber Value”, more fully defined in the definitions appendix below) in comparison to the costs associated with adding these customers, regardless of whether or not the costs are expensed or capitalized in the period (“Creation Cost”, more fully defined in the definitions appendix below). The Company also believes that Subscriber Value, Creation Costs, and Total Value Generated are useful metrics for investors because they present an unlevered view of all of the costs associated with new customers in a period compared to the expected future cash flows from these customers over a 30-year period, based on contracted pricing terms with its customers, which is not observable in any current or historic GAAP-derived metric. Management believes it is useful for investors to also evaluate the future expected cash flows from all customers that have been deployed through the respective measurement date, less estimated costs to maintain such systems and estimated distributions to tax equity partners in consolidated joint venture partnership flip structures, and distributions to project equity investors (“Gross Earning Assets”, more fully defined in the definitions appendix below). The Company also believes Gross Earning Assets is useful for management and investors because it represents the remaining future expected cash flows from existing customers, which is not a current or historic GAAP-derived measure.

    Various assumptions are made when calculating these metrics. Both Subscriber Value and Gross Earning Assets utilize a 6% rate to discount future cash flows to the present period. Furthermore, these metrics assume that customers renew after the initial contract period at a rate equal to 90% of the rate in effect at the end of the initial contract term. For Customer Agreements with 25-year initial contract terms, a 5-year renewal period is assumed. For a 20-year initial contract term, a 10-year renewal period is assumed. In all instances, we assume a 30-year customer relationship, although the customer may renew for additional years, or purchase the system. Estimated cost of servicing assets has been deducted and is estimated based on the service agreements underlying each fund.

    In-period volume metrics: Three Months Ended
    December 31, 2024
     
    Customer Additions   32,932  
    Subscriber Additions (included within Customer Additions)   30,709  
    Solar Energy Capacity Installed (in Megawatts)   242.4  
    Solar Energy Capacity Installed for Subscribers (in Megawatts)   232.0  
    Storage Capacity Installed (in Megawatt hours)   392.0  
         
    In-period value creation metrics: Three Months Ended
    December 31, 2024
     
    Subscriber Value Contracted Period $52,035  
    Subscriber Value Renewal Period $3,776  
    Subscriber Value $55,811  
    Creation Cost $36,634  
    Net Subscriber Value $19,177  
    Total Value Generated (in millions) $588.9  
         
    In-period environmental impact metrics: Three Months Ended
    December 31, 2024
     
    Positive Environmental Impact from Customers (over trailing twelve months, in millions of metric tons of CO2 avoidance)   4.0  
    Positive Expected Lifetime Environmental Impact from Customer Additions (in millions of metric tons of CO2 avoidance)   4.8  
         
    Period-end metrics: December 31, 2024  
    Customers   1,048,842  
    Subscribers (subset of Customers)   889,186  
    Households Served in Low-Income Multifamily Properties   21,129  
    Networked Solar Energy Capacity (in Megawatts)   7,531  
    Networked Solar Energy Capacity for Subscribers (in Megawatts)   6,436  
    Networked Storage Capacity (in Megawatt hours)   2,525  
    Annual Recurring Revenue (in millions) $1,644  
    Average Contract Life Remaining (in years)   17.6  
    Gross Earning Assets Contracted Period (in millions) $13,791  
    Gross Earning Assets Renewal Period (in millions) $4,043  
    Gross Earning Assets (in millions) $17,834  
    Net Earning Assets (in millions) $6,766  
           

    Figures presented above may not sum due to rounding. For adjustments related to Subscriber Value and Creation Cost, please see the supplemental Creation Cost and Net Subscriber Value calculation memo for each applicable period, which is available on investors.sunrun.com.

    Definitions

    Deployments represent solar or storage systems, whether sold directly to customers or subject to executed Customer Agreements (i) for which we have confirmation that the systems are installed, subject to final inspection, or (ii) in the case of certain system installations by our partners, for which we have accrued at least 80% of the expected project cost (inclusive of acquisitions of installed systems).

    Customer Agreements refer to, collectively, solar or storage power purchase agreements and leases.

    Subscriber Additions represent the number of Deployments in the period that are subject to executed Customer Agreements.

    Customer Additions represent the number of Deployments in the period.

    Solar Energy Capacity Installed represents the aggregate megawatt production capacity of our solar energy systems that were recognized as Deployments in the period.

    Solar Energy Capacity Installed for Subscribers represents the aggregate megawatt production capacity of our solar energy systems that were recognized as Deployments in the period that are subject to executed Customer Agreements.

    Storage Capacity Installed represents the aggregate megawatt hour capacity of storage systems that were recognized as Deployments in the period.

    Creation Cost represents the sum of certain operating expenses and capital expenditures incurred divided by applicable Customer Additions and Subscriber Additions in the period. Creation Cost is comprised of (i) installation costs, which includes the increase in gross solar energy system assets and the cost of customer agreement revenue, excluding depreciation expense of fixed solar assets, and operating and maintenance expenses associated with existing Subscribers, plus (ii) sales and marketing costs, including increases to the gross capitalized costs to obtain contracts, net of the amortization expense of the costs to obtain contracts, plus (iii) general and administrative costs, and less (iv) the gross profit derived from selling systems to customers under sale agreements and Sunrun’s product distribution and lead generation businesses. Creation Cost excludes stock based compensation, amortization of intangibles, and research and development expenses, along with other items the company deems to be non-recurring or extraordinary in nature. The gross margin derived from solar energy systems and product sales is included as an offset to Creation Cost since these sales are ancillary to the overall business model and lowers our overall cost of business. The sales, marketing, general and administrative costs in Creation Costs is inclusive of sales, marketing, general and administrative activities related to the entire business, including solar energy system and product sales. As such, by including the gross margin on solar energy system and product sales as a contra cost, the value of all activities of the Company’s segment are represented in the Net Subscriber Value.

    Subscriber Value represents the per subscriber value of upfront and future cash flows (discounted at 6%) from Subscriber Additions in the period, including expected payments from customers as set forth in Customer Agreements, net proceeds from tax equity finance partners, payments from utility incentive and state rebate programs, contracted net grid service program cash flows, projected future cash flows from solar energy renewable energy credit sales, less estimated operating and maintenance costs to service the systems and replace equipment, consistent with estimates by independent engineers, over the initial term of the Customer Agreements and estimated renewal period. For Customer Agreements with 25 year initial contract terms, a 5 year renewal period is assumed. For a 20 year initial contract term, a 10 year renewal period is assumed. In all instances, we assume a 30-year customer relationship, although the customer may renew for additional years, or purchase the system.

    Net Subscriber Value represents Subscriber Value less Creation Cost.

    Total Value Generated represents Net Subscriber Value multiplied by Subscriber Additions.

    Customers represent the cumulative number of Deployments, from the company’s inception through the measurement date.

    Subscribers represent the cumulative number of Customer Agreements for systems that have been recognized as Deployments through the measurement date.

    Networked Solar Energy Capacity represents the aggregate megawatt production capacity of our solar energy systems that have been recognized as Deployments, from the company’s inception through the measurement date.

    Networked Solar Energy Capacity for Subscribers represents the aggregate megawatt production capacity of our solar energy systems that have been recognized as Deployments, from the company’s inception through the measurement date, that have been subject to executed Customer Agreements.

    Networked Storage Capacity represents the aggregate megawatt hour capacity of our storage systems that have been recognized as Deployments, from the company’s inception through the measurement date.

    Gross Earning Assets is calculated as Gross Earning Assets Contracted Period plus Gross Earning Assets Renewal Period.

    Gross Earning Assets Contracted Period represents the present value of the remaining net cash flows (discounted at 6%) during the initial term of our Customer Agreements as of the measurement date. It is calculated as the present value of cash flows (discounted at 6%) that we would receive from Subscribers in future periods as set forth in Customer Agreements, after deducting expected operating and maintenance costs, equipment replacements costs, distributions to tax equity partners in consolidated joint venture partnership flip structures, and distributions to project equity investors. We include cash flows we expect to receive in future periods from tax equity partners, government incentive and rebate programs, contracted sales of solar renewable energy credits, and awarded net cash flows from grid service programs with utilities or grid operators.

    Gross Earning Assets Renewal Period is the forecasted net present value we would receive upon or following the expiration of the initial Customer Agreement term but before the 30th anniversary of the system’s activation (either in the form of cash payments during any applicable renewal period or a system purchase at the end of the initial term), for Subscribers as of the measurement date. We calculate the Gross Earning Assets Renewal Period amount at the expiration of the initial contract term assuming either a system purchase or a renewal, forecasting only a 30-year customer relationship (although the customer may renew for additional years, or purchase the system), at a contract rate equal to 90% of the customer’s contractual rate in effect at the end of the initial contract term. After the initial contract term, our Customer Agreements typically automatically renew on an annual basis and the rate is initially set at up to a 10% discount to then-prevailing utility power prices.

    Net Earning Assets represents Gross Earning Assets, plus total cash, less adjusted debt and less pass-through financing obligations, as of the same measurement date. Debt is adjusted to exclude a pro-rata share of non-recourse debt associated with funds with project equity structures along with debt associated with the company’s ITC safe harboring facility. Because estimated cash distributions to our project equity partners are deducted from Gross Earning Assets, a proportional share of the corresponding project level non-recourse debt is deducted from Net Earning Assets, as such debt would be serviced from cash flows already excluded from Gross Earning Assets.

    Cash Generation is calculated using the change in our unrestricted cash balance from our consolidated balance sheet, less net proceeds (or plus net repayments) from all recourse debt (inclusive of convertible debt), and less any primary equity issuances or net proceeds derived from employee stock award activity (or plus any stock buybacks or dividends paid to common stockholders) as presented on the Company’s consolidated statement of cash flows. The Company expects to continue to raise tax equity and asset-level non-recourse debt to fund growth, and as such, these sources of cash are included in the definition of Cash Generation. Cash Generation also excludes long-term asset or business divestitures and equity investments in external non-consolidated businesses (or less dividends or distributions received in connection with such equity investments). Restricted cash in a reserve account with a balance equal to the amount outstanding of 2026 convertible notes is considered unrestricted cash for the purposes of calculating Cash Generation.

    Annual Recurring Revenue represents revenue arising from Customer Agreements over the following twelve months for Subscribers that have met initial revenue recognition criteria as of the measurement date.

    Average Contract Life Remaining represents the average number of years remaining in the initial term of Customer Agreements for Subscribers that have met revenue recognition criteria as of the measurement date.

    Households Served in Low-Income Multifamily Properties represent the number of individual rental units served in low-income multi-family properties from shared solar energy systems deployed by Sunrun. Households are counted when the solar energy system has interconnected with the grid, which may differ from Deployment recognition criteria.

    Positive Environmental Impact from Customers represents the estimated reduction in carbon emissions as a result of energy produced from our Networked Solar Energy Capacity over the trailing twelve months. The figure is presented in millions of metric tons of avoided carbon emissions and is calculated using the Environmental Protection Agency’s AVERT tool. The figure is calculated using the most recent published tool from the EPA, using the current-year avoided emission factor for distributed resources on a state by state basis. The environmental impact is estimated based on the system, regardless of whether or not Sunrun continues to own the system or any associated renewable energy credits.

    Positive Expected Lifetime Environmental Impact from Customer Additions represents the estimated reduction in carbon emissions over thirty years as a result of energy produced from solar energy systems that were recognized as Deployments in the period. The figure is presented in millions of metric tons of avoided carbon emissions and is calculated using the Environmental Protection Agency’s AVERT tool. The figure is calculated using the most recent published tool from the EPA, using the current-year avoided emission factor for distributed resources on a state by state basis, leveraging our estimated production figures for such systems, which degrade over time, and is extrapolated for 30 years. The environmental impact is estimated based on the system, regardless of whether or not Sunrun continues to own the system or any associated renewable energy credits.

    Total Cash represents the total of the restricted cash balance and unrestricted cash balance from our consolidated balance sheet.

    Investor & Analyst Contact:

    Patrick Jobin
    SVP, Deputy CFO & Investor Relations Officer
    investors@sunrun.com

    Media Contact:

    Wyatt Semanek
    Director, Corporate Communications
    press@sunrun.com

    The MIL Network

  • MIL-OSI: Talen Energy Reports Full Year 2024 Results, Exceeds 2024 Guidance and Reaffirms 2025 Guidance

    Source: GlobeNewswire (MIL-OSI)

    Earnings Release Highlights

    • Full year GAAP Net Income (Loss) Attributable to Stockholders of $998 million.
    • Full year Adjusted EBITDA of $770 million and Adjusted Free Cash Flow of $283 million, exceeding the 2024 guidance midpoints.
    • Reaffirming 2025 guidance; 2026 outlook unchanged.
    • Reached reliability-must-run (“RMR”) settlement agreement with PJM and key stakeholders to run Brandon Shores and H.A. Wagner generation facilities through May 31, 2029.
    • Repurchased approximately 13 million shares in 2024 (22% of total outstanding shares).

    HOUSTON, Feb. 27, 2025 (GLOBE NEWSWIRE) — Talen Energy Corporation (“Talen,” the “Company,” “we,” or “our”) (NASDAQ: TLN), an independent power producer dedicated to powering the future, today reported its full year 2024 financial and operating results.

    “Talen had an exciting year focused on unlocking value from existing assets. Our fleet ran well this year, earning $770 million of Adjusted EBITDA and $283 million of Adjusted Free Cash Flow. We sold our data center campus to AWS and announced a major agreement providing power directly to them, making Talen the first power company to do so. We are actively executing under this arrangement and pursuing commercial and regulatory solutions for the Susquehanna ISA amendment,” said Talen President and Chief Executive Officer Mac McFarland.

    “We sold our ERCOT assets earlier in the year, realizing significant value that was largely returned to our shareholders, and in Q4, we reached a settlement with PJM and other stakeholders to continue running our Brandon Shores and H.A. Wagner generation facilities through May 2029, supporting grid reliability in Maryland.” McFarland continued. “We have simplified our capital structure and prioritized shareholder returns, repurchasing 22% of our outstanding shares this year. We remain focused on maximizing value and cash flow per share.”

    Summary of Financial and Operating Results (Unaudited)

    (Millions of Dollars)   Year Ended
    December 31,
    2024
    GAAP Net Income (Loss) Attributable to Stockholders     $998
    Adjusted EBITDA     770
    Adjusted Free Cash Flow     283
           
        Year Ended
    December 31,
    2024
      Year Ended
    December 31,
    2023
    Total Generation (TWh) (a)   36.3     32.5  
    Carbon-Free Generation   50 %   55 %
    OSHA TRIR (b)   0.34     0.58  
    Fleet EFOF (c)   2.2 %   5.5 %
                 

    __________________
    (a) Total generation is net of station use consumption, where applicable, includes volumes produced by Susquehanna in support of Nautilus operations and includes generation from ERCOT assets through April 2024.
    (b) OSHA Total Recordable Incident Rate (“OSHA TRIR”) is the number of recordable incidents x 200,000 / total number of manhours worked. Only includes Talen-operated generation facilities (i.e., excludes Conemaugh and Keystone).
    (c) Fleet Equivalent Forced Outage Factor (“Fleet EFOF”) is the percentage of a given period in which a generating unit is not available due to forced outages and forced de-rates. Represents all generation facilities, including our portion of partially-owned facilities.

    For the year ended December 31, 2024, we reported GAAP Net Income (Loss) Attributable to Stockholders of $998 million, Adjusted EBITDA of $770 million and Adjusted Free Cash Flow of $283 million. 2024 Adjusted EBITDA and Adjusted Free Cash Flow exceeded the 2024 guidance midpoints of $765 million and $275 million, respectively.

    Given the impacts of fresh start accounting and the implementation of the plan of reorganization in the second quarter 2023, our full year 2024 results are not comparable to 2023.

    Full year 2024 results were supported by strong operational performance across the generation fleet, the benefits from hedging activities, the impact of the Nuclear PTC, and disciplined cost management, despite the absence of earnings from the ERCOT generation portfolio that was sold in May 2024.

    Our generation fleet continued to run reliably and safely, with a Fleet EFOF of 2.2% and an OSHA TRIR of 0.34. Total generation was 36.3 TWh, with 50% contributed from carbon-free nuclear generation at our Susquehanna nuclear facility. Also, our PJM gas-fired assets were dispatched more frequently during times of peak load than they were in 2023.

    Reaffirming 2025 Guidance; 2026 Outlook Unchanged

    (Millions of Dollars) Range
    2025E Adjusted EBITDA $925 – $1,175
    2025E Adjusted Free Cash Flow $395 – $595
       
    (Millions of Dollars) Range
    2026E Adjusted EBITDA $1,130 – $1,530
    2026E Adjusted Free Cash Flow $535 – $895
       

    RMR Arrangements

    In December 2024, we reached an agreement with PJM, FERC staff, Maryland PSC and public utilities on the terms of RMR arrangements for our Brandon Shores and H.A. Wagner generation facilities. On January 27, 2025, we filed with FERC the resulting Joint Offers of Settlement regarding both facilities’ RMR Continuing Operations Rates Schedules, and they remain subject to FERC approval. If approved, the proposed RMR arrangements will extend the operating life of these facilities through May 31, 2029, or until such time as the necessary transmission upgrades are placed into service. Beginning June 1, 2025, we expect to receive $145 million annually for Brandon Shores and $35 million for H.A. Wagner with some performance incentives. Additionally, we expect to receive reimbursement for variable costs and approved project investments.

    Update on Share Repurchase Program

    Since the start of 2024, we have repurchased approximately 22% of our outstanding shares for a total of $1.95 billion, with $1.1 billion of remaining share repurchase program capacity through year-end 2026. During the fourth quarter 2024, we repurchased approximately 5 million shares of stock from our largest shareholder. All share repurchase amounts are excluding transaction costs.

    Balance Sheet and Liquidity

    We are focused on maintaining net leverage below our target of 3.5x net debt-to-Adjusted EBITDA, along with ample liquidity. As of February 21, 2025, we had total available liquidity of approximately $1.2 billion, comprised of $474 million of unrestricted cash and $700 million of available capacity under the revolving credit facility. Our current net leverage ratio, utilizing the 2024 Adjusted EBITDA and net debt balance as of February 21, 2025, is approximately 3.3x.

    Update on Hedging Activities

    As of December 31, 2024, including the impact of the Nuclear PTC, we had hedged approximately 89% of our expected generation volumes for 2025 and 33% for 2026. The Company’s hedging program is a key component of our comprehensive risk policy and supports the objective of increasing cash flow stability while maintaining upside optionality.

    As an update on nuclear fuel supply activities, the nuclear fuel cycle is fully contracted through the 2027 fuel load, almost entirely contracted through 2028, and over 70% contracted through 2029. These percentages are based on total nuclear fuel costs across all phases and assume current market pricing for the portion not yet under contract.

    Earnings Call

    The Company will hold an earnings call on Thursday, February 27, 2025, at 4:30 p.m. EST (3:30 p.m. CST). To listen to the earnings call, please register in advance for the webcast here. For participants joining the call via phone, please register here prior to the start time to receive dial-in information. For those unable to participate in the live event, a digital replay of the earnings call will be archived for approximately one year and available on Talen’s Investor Relations website at https://ir.talenenergy.com/news-events/events.

    About Talen

    Talen Energy (NASDAQ: TLN) is a leading independent power producer and energy infrastructure company dedicated to powering the future. We own and operate approximately 10.7 gigawatts of power infrastructure in the United States, including 2.2 gigawatts of nuclear power and a significant dispatchable fossil fleet. We produce and sell electricity, capacity, and ancillary services into wholesale U.S. power markets, with our generation fleet principally located in the Mid-Atlantic and Montana. Our team is committed to generating power safely and reliably and delivering the most value per megawatt produced. Talen is also powering the digital infrastructure revolution. We are well-positioned to capture this significant growth opportunity, as data centers serving artificial intelligence increasingly demand more reliable, clean power. Talen is headquartered in Houston, Texas. For more information, visit https://www.talenenergy.com/.

    Investor Relations:

    Ellen Liu
    Senior Director, Investor Relations
    InvestorRelations@talenenergy.com

    Media:

    Taryne Williams
    Director, Corporate Communications
    Taryne.Williams@talenenergy.com

    Forward-Looking Statements

    This communication contains forward-looking statements within the meaning of the federal securities laws, which statements are subject to substantial risks and uncertainties. These forward-looking statements are intended to qualify for the safe harbor from liability established by the Private Securities Litigation Reform Act of 1995. All statements other than statements of historical fact included in this communication, or incorporated by reference into this communication, are forward-looking statements. Throughout this communication, we have attempted to identify forward-looking statements by using words such as “anticipate,” “believe,” “continue,” “could,” “estimate,” “expect,” “forecasts,” “goal,” “intend,” “may,” “plan,” “potential,” “predict,” “project,” “seek,” “should,” “will,” or other forms of these words or similar words or expressions or the negative thereof, although not all forward-looking statements contain these terms. Forward-looking statements address future events and conditions concerning, among other things, capital expenditures, earnings, litigation, regulatory matters, hedging, liquidity and capital resources and accounting matters. Forward-looking statements are subject to substantial risks and uncertainties that could cause our future business, financial condition, results of operations or performance to differ materially from our historical results or those expressed or implied in any forward-looking statement contained in this communication. All of our forward-looking statements include assumptions underlying or relating to such statements that may cause actual results to differ materially from expectations, and are subject to numerous factors that present considerable risks and uncertainties.

    TALEN ENERGY CORPORATION AND SUBSIDIARIES

    CONSOLIDATED STATEMENTS OF OPERATIONS

     
        Successor     Predecessor
    (Millions of Dollars, except share data)   Year Ended
    December 31, 2024
      May 18 through
    December 31, 2023
        January 1 through
    May 17, 2023
    Capacity revenues   $ 192     $ 133       $ 108  
    Energy and other revenues     1,881       1,156         1,042  
    Unrealized gain (loss) on derivative instruments     42       55         60  
    Operating Revenues     2,115       1,344         1,210  
                   
    Fuel and energy purchases     (694 )     (424 )       (176 )
    Nuclear fuel amortization     (123 )     (108 )       (33 )
    Unrealized gain (loss) on derivative instruments     20       (3 )       (123 )
    Energy Expenses     (797 )     (535 )       (332 )
                   
    Operating Expenses              
    Operation, maintenance and development     (592 )     (358 )       (285 )
    General and administrative     (163 )     (93 )       (51 )
    Depreciation, amortization and accretion     (298 )     (165 )       (200 )
    Impairments     (1 )     (3 )       (381 )
    Other operating income (expense), net     (38 )     (30 )       (37 )
    Operating Income (Loss)     226       160         (76 )
    Nuclear decommissioning trust funds gain (loss), net     178       108         57  
    Interest expense and other finance charges     (238 )     (176 )       (163 )
    Reorganization income (expense), net                   799  
    Gain (loss) on sale of assets, net     884       7         50  
    Other non-operating income (expense), net     61       95         10  
    Income (Loss) Before Income Taxes     1,111       194         677  
    Income tax benefit (expense)     (98 )     (51 )       (212 )
    Net Income (Loss)     1,013       143         465  
    Less: Net income (loss) attributable to noncontrolling interest     15       9         (14 )
    Net Income (Loss) Attributable to Stockholders (Successor) / Member (Predecessor)   $ 998     $ 134       $ 479  
    Per Common Share (Successor)              
    Net Income (Loss) Attributable to Stockholders – Basic   $ 18.40     $ 2.27       N/A
    Net Income (Loss) Attributable to Stockholders – Diluted   $ 17.67     $ 2.26       N/A
    Weighted-Average Number of Common Shares Outstanding – Basic (in thousands)     54,254       59,029       N/A
    Weighted-Average Number of Common Shares Outstanding – Diluted (in thousands)     56,486       59,399       N/A
                           

     

    TALEN ENERGY CORPORATION AND SUBSIDIARIES

    CONSOLIDATED BALANCE SHEETS

     
        Successor
    (Millions of Dollars, except share data)   December 31,
    2024
      December 31,
    2023
    Assets        
    Cash and cash equivalents   $ 328     $ 400  
    Restricted cash and cash equivalents     37       501  
    Accounts receivable     123       137  
    Inventory, net     302       375  
    Derivative instruments     66       89  
    Other current assets     184       52  
    Total current assets     1,040       1,554  
    Property, plant and equipment, net     3,154       3,839  
    Nuclear decommissioning trust funds     1,724       1,575  
    Derivative instruments     5       6  
    Other noncurrent assets     183       147  
    Total Assets   $ 6,106     $ 7,121  
             
    Liabilities and Equity        
    Long-term debt, due within one year   $ 17     $ 9  
    Accrued interest     18       32  
    Accounts payable and other accrued liabilities     266       344  
    Derivative instruments           32  
    Other current liabilities     154       69  
    Total current liabilities     455       486  
    Long-term debt     2,987       2,811  
    Derivative instruments     7       11  
    Postretirement benefit obligations     305       368  
    Asset retirement obligations and accrued environmental costs     468       469  
    Deferred income taxes     362       407  
    Other noncurrent liabilities     135       35  
    Total Liabilities   $ 4,719     $ 4,587  
    Commitments and Contingencies        
             
    Stockholders’ Equity        
    Common stock ($0.001 par value 350,000,000 shares authorized) (a)   $     $  
    Additional paid-in capital     1,725       2,346  
    Accumulated retained earnings (deficit)     (326 )     134  
    Accumulated other comprehensive income (loss)     (12 )     (23 )
    Total Stockholders’ Equity     1,387       2,457  
    Noncontrolling interests           77  
    Total Equity     1,387       2,534  
    Total Liabilities and Equity   $ 6,106     $ 7,121  
                     

    __________________

    (a) 45,961,910 and 59,028,843 shares issued and outstanding as of December 31, 2024 (Successor) and December 31, 2023 (Successor), respectively.

    TALEN ENERGY CORPORATION AND SUBSIDIARIES

    CONSOLIDATED STATEMENTS OF CASH FLOWS

     
        Successor     Predecessor
    (Millions of Dollars)   Year Ended
    December 31, 2024
      May 18 through
    December 31, 2023
        January 1 through
    May 17, 2023
    Operating Activities              
    Net income (loss)   $ 1,013     $ 143       $ 465  
    Non-cash reconciliation adjustments:              
    (Gain) loss on AWS Data Campus Sale and ERCOT Sale     (886 )              
    Depreciation, amortization and accretion     285       157         208  
    NDT funds (gain) loss, net (excluding interest and fees)     (130 )     (78 )       (43 )
    Nuclear fuel amortization     123       108         33  
    Unrealized (gains) losses on derivative instruments     (69 )     (40 )       65  
    Deferred income taxes     (46 )     55         195  
    Impairments     1       3         381  
    (Gain) loss on sales of assets, net           (7 )       (50 )
    Reorganization (income) expense, net                   (933 )
    Other     (26 )     7         7  
    Changes in assets and liabilities:              
    Inventory, net     67       (68 )       10  
    Accounts receivable     14       8         261  
    Other assets     (61 )     147         98  
    Accounts payable and accrued liabilities     (69 )     (49 )       (69 )
    Accrued interest     (15 )     28         (124 )
    Other liabilities     55       (12 )       (42 )
    Net cash provided by (used in) operating activities     256       402         462  
    Investing Activities              
    NDT funds investment purchases     (2,295 )     (1,290 )       (959 )
    NDT funds investment sale proceeds     2,263       1,265         949  
    Proceeds from AWS Data Campus Sale and ERCOT Sale     1,398                
    Nuclear fuel expenditures     (104 )     (45 )       (49 )
    Property, plant and equipment expenditures     (85 )     (116 )       (138 )
    Equity investments in affiliates     (10 )     (5 )       (8 )
    Proceeds from the sale of assets     2       8         46  
    Other investing activities     2       12         2  
    Net cash provided by (used in) investing activities     1,171       (171 )       (157 )
                               
    TALEN ENERGY CORPORATION AND SUBSIDIARIES

    CONSOLIDATED STATEMENTS OF CASH FLOWS

     
        Successor     Predecessor
    (Millions of Dollars)   Year Ended
    December 31, 2024
      May 18 through
    December 31, 2023
        January 1 through
    May 17, 2023
    Financing Activities              
    Share repurchases     (1,958 )              
    TES debt issuance     849                
    TES debt repayments     (479 )              
    Cumulus Digital TLF repayment     (182 )     (15 )        
    Repurchase of noncontrolling interest     (125 )     (19 )        
    Cash settlement of restricted stock units     (32 )              
    Exercise or repurchase of warrants     (16 )     (40 )        
    Deferred financing costs     (13 )     (7 )       (74 )
    LMBE-MC TLB payments           (294 )       (7 )
    TLB-1 proceeds, net           288          
    Repayment of prepetition secured indebtedness                   (3,898 )
    Financing proceeds at Emergence, net of discount                   2,219  
    Contributions from member                   1,393  
    Payment of make-whole premiums on prepetition secured indebtedness                   (152 )
    Derivatives with financing elements                   (20 )
    Other     (7 )     3          
    Net cash provided by (used in) financing activities     (1,963 )     (84 )       (539 )
    Net Increase (Decrease) in Cash and Cash Equivalents and Restricted Cash and Cash Equivalents     (536 )     147         (234 )
    Beginning of period cash and cash equivalents and restricted cash and cash equivalents     901       754         988  
    End of period cash and cash equivalents and restricted cash and cash equivalents   $ 365     $ 901       $ 754  
                               

    Non-GAAP Financial Measures

    Adjusted EBITDA and Adjusted Free Cash flow, which we use as measures of our performance and liquidity, are not financial measures prepared under GAAP. Non-GAAP financial measures do not have definitions under GAAP and may be defined and calculated differently by, and not be comparable to, similarly titled measures used by other companies. Non-GAAP measures are not intended to replace the most comparable GAAP measures as indicators of performance. Generally, a non-GAAP financial measures is a numerical measure of financial performance, financial position, or cash flows that excludes (or includes) amounts that are included in (or excluded from) the most directly comparable measure calculated and presented in accordance with GAAP. Management cautions readers not to place undue reliance on the following non-GAAP financial measures, but to also consider them along with their most directly comparable GAAP financial measures. Non-GAAP measures have limitations as analytical tools and should not be considered in isolation or as a substitute for analyzing our results as reported under GAAP.

    Adjusted EBITDA

    We use Adjusted EBITDA to: (i) assist in comparing operating performance and readily view operating trends on a consistent basis from period to period without certain items that may distort financial results; (ii) plan and forecast overall expectations and evaluate actual results against such expectations; (iii) communicate with our Board of Directors, shareholders, creditors, analysts, and the broader financial community concerning our financial performance; (iv) set performance metrics for our annual short-term incentive compensation; and (v) assess compliance with our indebtedness.

    Adjusted EBITDA is computed as net income (loss) adjusted, among other things, for certain: (i) nonrecurring charges; (ii) non-recurring gains; (iii) non-cash and other items; (iv) unusual market events; (v) any depreciation, amortization, or accretion; (vi) mark-to-market gains or losses; (vii) gains and losses on the nuclear facility decommissioning trust (“NDT”); (viii) gains and losses on asset sales, dispositions, and asset retirement; (ix) impairments, obsolescence, and net realizable value charges; (x) interest expense; (xi) income taxes; (xii) legal settlements, liquidated damages, and contractual terminations; (xiii) development expenses; (xiv) noncontrolling interests, except where otherwise noted; and (xv) other adjustments. Such adjustments are computed consistently with the provisions of our indebtedness to the extent that they can be derived from the financial records of the business. Pursuant to TES’s debt agreements, Cumulus Digital contributes to Adjusted EBITDA beginning in the first quarter 2024, following termination of the Cumulus Digital credit facility and associated cash flow sweep.

    Additionally, we believe investors commonly adjust net income (loss) information to eliminate the effect of nonrecurring restructuring expenses and other non-cash charges, which can vary widely from company to company and from period to period and impair comparability. We believe Adjusted EBITDA is useful to investors and other users of our financial statements to evaluate our operating performance because it provides an additional tool to compare business performance across companies and between periods. Adjusted EBITDA is widely used by investors to measure a company’s operating performance without regard to such items described above. These adjustments can vary substantially from company to company and period to period depending upon accounting policies, book value of assets, capital structure, and the method by which assets were acquired.

    Adjusted Free Cash Flow

    Adjusted Free Cash Flow is utilized by our chief operating decision makers to evaluate cash flow activities. Adjusted Free Cash Flow is computed as Adjusted EBITDA reduced by capital expenditures (including nuclear fuel but excluding development, growth, and (or) conversion capital expenditures), cash payments for interest and finance charges, cash payments for taxes (excluding income taxes paid from the NDT, taxes paid or deductions taken as a result of strategic asset sales, and benefits of the Nuclear PTC utilized to reduce taxes paid), and pension contributions.

    We believe Adjusted Free Cash Flow is useful to investors and other users of our financial statements in evaluating our operating performance because it provides them with an additional tool to determine a company’s ability to meet future obligations and to compare business performance across companies and across periods. Adjusted Free Cash Flow is widely used by investors to measure a company’s levered cash flow without regard to items such as ARO settlements; nonrecurring development, growth and conversion expenditures; and cash proceeds or payments for the sale or purchase of assets, which can vary substantially from company to company and from period to period depending upon accounting methods, book value of assets, capital structure, and the method by which assets were acquired.

    Adjusted EBITDA / Adjusted Free Cash Flow Reconciliation

    The following table presents a reconciliation of the GAAP financial measures of “Net Income (Loss)” presented on the Consolidated Statements of Operations to the non-GAAP financial measures of Adjusted EBITDA and Adjusted Free Cash Flow:

        Successor     Predecessor
    (Millions of Dollars)   Year Ended
    December 31, 2024
      May 18 through
    December 31, 2023
        January 1 through
    May 17, 2023
    Net Income (Loss)   $ 1,013     $ 143       $ 465  
    Adjustments              
    Interest expense and other finance charges     238       176         163  
    Income tax (benefit) expense     98       51         212  
    Depreciation, amortization and accretion     298       165         200  
    Nuclear fuel amortization     123       108         33  
    Reorganization (gain) loss, net (a)                   (799 )
    Unrealized (gain) loss on commodity derivative contracts     (62 )     (52 )       63  
    Nuclear decommissioning trust funds (gain) loss, net     (178 )     (108 )       (57 )
    Stock-based compensation expense     33       19          
    Long-term incentive compensation expense     21       2          
    (Gain) loss on asset sales, net (b)     (884 )     (7 )       (50 )
    Non-cash impairments (c)     1       3         381  
    Legal settlements and litigation costs (d)     (10 )     (84 )       1  
    Unusual market events (d)     (1 )     (19 )       14  
    Net periodic defined benefit cost     14       2         (3 )
    Operational and other restructuring activities (e) (f)     76       48         17  
    Development expenses     1       7         10  
    Non-cash inventory net realizable value, obsolescence, and other charges (g)     20       4         56  
    Noncontrolling interest     (21 )     (42 )       (14 )
    Other     (10 )     10         3  
    Total Adjusted EBITDA   $ 770     $ 426       $ 695  
                   
    Capital expenditures, net     (177 )     (112 )       (96 )
    Interest and finance charge payments     (252 )     (132 )       (173 )
    Tax payments     (4 )     (5 )       (5 )
    Pension contributions     (54 )     (8 )       (3 )
    Total Adjusted Free Cash Flow   $ 283     $ 169       $ 418  
                               

    _______________

    (a) See Note 4 to the FY 2024 Financial Statements for additional information.
    (b) See Note 20 to the FY 2024 Financial Statements for additional information.
    (c) See Note 10 to the FY 2024 Financial Statements for additional information.
    (d) See Note 12 to the FY 2024 Financial Statements for additional information.
    (e) The year ended December 31, 2024 (Successor) primarily includes the effects of nonrecurring ERCOT hedge settlements that occurred after the ERCOT Sale and severance payments associated with cost reduction initiatives.
    (f) The periods from May 18 through December 31, 2023 (Successor) and from January 1 through May 17, 2023 (Predecessor) include the effects of nonrecurring costs associated with exit from the Restructuring, severance costs associated with cost reduction initiatives, and nonrecurring post-Restructuring strategic initiative costs.
    (g) See Note 8 to the FY 2024 Financial Statements for additional information.

    Adjusted EBITDA / Adjusted Free Cash Flow Reconciliation: 2025 Guidance

        2025E
    (Millions of dollars)   Low   High
    Net Income (Loss)   $ 155     $ 375  
             
    Adjustments        
    Interest expense and other finance charges     235       245  
    Income tax (benefit) expense     60       80  
    Depreciation, amortization and accretion     295       295  
    Nuclear fuel amortization     105       105  
    Unrealized (gain) loss on commodity derivative contracts     75       75  
    Adjusted EBITDA   $ 925     $ 1,175  
             
    Capital expenditures, net   $ (195 )   $ (205 )
    Interest and finance charge payments     (215 )     (225 )
    Tax payments     (50 )     (70 )
    Pension contributions     (70 )     (80 )
    Adjusted Free Cash Flow   $ 395     $ 595  
                     

    _______________

    Note: Figures are rounded to the nearest $5 million.

    The MIL Network

  • MIL-OSI: Cipher Mining Announces Participation in Upcoming Investor and Industry Conferences

    Source: GlobeNewswire (MIL-OSI)

    NEW YORK, Feb. 27, 2025 (GLOBE NEWSWIRE) — Cipher Mining Inc. (NASDAQ:CIFR) (“Cipher” or the “Company”), a leader in the development of industrial-scale data centers, today announced its participation in several upcoming industry conferences. Cipher’s CEO, Tyler Page, will be featured in various fireside chats to discuss the company’s existing site capacity, growth strategy, bitcoin mining and HPC opportunities. Webcast links, if available, will be shared on Cipher’s X and LinkedIn platforms ahead of each event.

    Details of the Events:

    Event: Morgan Stanley Energy & Power Conference
    Date: Tuesday, March 4th, 2025
    Event: Morgan Stanley Technology, Media & Telecom Conference
    Date: Thursday, March 6th, 2025
    Event: 2025 Cantor Fitzgerald Global Technology Conference
    Date: Wednesday, March 12th, 2025

    The webcast replays will also be available in the Events section of Cipher’s website at https://investors.ciphermining.com. For additional information, please contact the Cipher investor relations team at investors@ciphermining.com.

    About Cipher

    Cipher is focused on the development and operation of industrial-scale data centers for bitcoin mining and HPC hosting. Cipher aims to be a market leader in innovation, including in bitcoin mining growth, data center construction and as a hosting partner to the world’s largest HPC companies. To learn more about Cipher, please visit https://www.ciphermining.com/.

    Website Disclosure

    The company maintains a dedicated investor website at https://investors.ciphermining.com/ (“Investors’ Website”). Financial and other important information regarding the Company is routinely posted on and accessible through the Investors Website. Cipher uses its Investors’ Website as a distribution channel of material information about the Company, including through press releases, investor presentations, reports and notices of upcoming events. Cipher intends to utilize its Investors’ Website as a channel of distribution to reach public investors and as a means of disclosing material non-public information for complying with disclosure obligations under Regulation FD. In addition, you may sign up to automatically receive email alerts and other information about the Company by visiting the “Email Alerts” option under the Investors Resources section of Cipher’s Investors’ Website and submitting your email address.

    Contacts:
    Investor Contact:
    Courtney Knight
    Head of Investor Relations at Cipher Mining
    Courtney.knight@ciphermining.com

    Media Contact:
    Ryan Dicovitsky / Kendal Till
    Dukas Linden Public Relations
    CipherMining@DLPR.com

    The MIL Network

  • MIL-OSI: Epsilon Energy Ltd. Announces the Following Headlines

    Source: GlobeNewswire (MIL-OSI)

    • Board declares dividend of $0.0625 per common share
    • Company announces the timing of its 2024 year end earnings release and conference call

    HOUSTON, Feb. 27, 2025 (GLOBE NEWSWIRE) — Epsilon Energy Ltd. (“Epsilon” or the “Company”) (NASDAQ: EPSN) today announced that its Board of Directors has declared a dividend of $0.0625 per share of common stock (annualized $0.25/sh) to the stock holders of record at the close of business on March 13, 2025, payable on March 31, 2025. All dividends paid by the Company are “eligible dividends” as defined in subsection 89(1) of the Income Tax Act (Canada), unless indicated otherwise.

    The Company also announced that it will issue its year end 2024 earnings release on Wednesday, March 19, 2025 after the market close and host a conference call to discuss its financial and operating results on Thursday, March 20, 2025 at 10:30 a.m. Central Time (11:30 a.m. Eastern Time).

    Interested parties in the United States and Canada may participate toll-free by dialing (833) 816-1385. International parties may participate by dialing (412) 317-0478. Participants should ask to be joined to the “Epsilon Energy 2024 Year End Earnings Conference Call.”

    A webcast can be viewed at: https://event.choruscall.com/mediaframe/webcast.html?webcastid=lEJXH1I5. A webcast replay will be available on the Company’s website (www.epsilonenergyltd.com) following the call.

    About Epsilon

    Epsilon Energy Ltd. is a North American onshore natural gas and oil production and gathering company with assets in Pennsylvania, Texas, New Mexico, Oklahoma, and Alberta, Canada.

    Contact Information:

    281-670-0002

    Jason Stabell
    Chief Executive Officer
    Jason.Stabell@EpsilonEnergyLTD.com

    Andrew Williamson
    Chief Financial Officer
    Andrew.Williamson@EpsilonEnergyLTD.com

    The MIL Network

  • MIL-OSI USA: VIDEO: Capito Votes to Overturn Biden–Era Natural Gas Tax

    US Senate News:

    Source: United States Senator for West Virginia Shelley Moore Capito
    To watch Chairman Capito’s floor remarks, click here.
    WASHINGTON, D.C. – Today, U.S. Senator Shelley Moore Capito (R-W.Va.), Chairman of the Senate Environment and Public Works (EPW) Committee, voted to overturn the Biden Environmental Protection Agency’s (EPA) Waste Emissions Charge (WEC) regulation as part of the Methane Emissions Reduction Program (MERP) under the Democrats’ Inflation Reduction Act. This rule enabled the collection of the Democrats’ natural gas tax, which would hurt American energy generation, damage our economy, and be detrimental to energy jobs across our country. The Senate approved the Congressional Review Act (CRA) joint resolution of disapproval, which was introduced by U.S. Senator John Hoeven (R-N.D.) and co-sponsored by Chairman Capito, by a vote of 52-47.
    Prior to the final vote on the CRA, Chairman Capito delivered remarks on the Senate floor outlining the consequences of the natural gas tax and the importance of natural gas to American energy dominance, and urged her colleagues to support the measure.
    Below are the floor remarks of Chairman Shelley Moore Capito (R-W.Va.) as delivered.
    “I rise today in support of my friend from North Dakota, Senator Hoeven’s, Congressional Review Act resolution to block the implementation of the Biden administration’s Waste Emissions Charge, otherwise known as the natural gas tax.
    “Since the day this regulation was finalized last November, I pledged that I would work with President Trump and my colleagues in the Congress to repeal this misguided, anti-energy tax. Today in the Senate, that is exactly what we’re working to do.
    “We must recognize that we are in a critical moment for American energy. The North American Energy Reliability Corporation has found that over the next 10 years, due to a rise in energy consumption and the early retirement of our existing fossil fuel generation, our country could face major electric generation and reliability concerns.
    “We must take action now to ensure that our future demand is met, that the lights remain on, our homes remain warm, and our economy keeps moving for Americans all across this country. We can do this by continuing to invest in natural gas.
    “Over 60% of American homes, every day, heat their homes, their water, or their food with natural gas. Natural gas is responsible for over 40% of electricity generation, and fuels more than half of our industrial sector’s process heat. While the natural gas tax fails to recognize this reality, let’s look at what is true.
    “Fracking and shale gas have both revolutionized and transformed American energy, leading to lower prices, job growth, and increased American energy security. According to the Energy Information Administration, the rapid expansion of natural gas-fired power plants, in this country, has decreased the power sector’s carbon dioxide emissions by 35% over the last 25 years.
    “Natural gas has the potential to further reduce American greenhouse gas emissions if we continue to increase production.
    “Natural gas is affordable, reliable, and a clean source of energy, vital to our country and our economy. We should be expanding natural gas production, not restricting it. Instead, the natural gas tax will constrain American natural gas production, leading to increased energy prices and providing a boost to the production of natural gas in Russia.
    “Simply put, repealing the natural gas tax is a win for our economy, a win for our natural security, and a win for our environment.
    “As part of establishing this tax, the Democrats’ so-called ‘Inflation Reduction Act’ ordered the EPA to revise its subpart W requirements in order to facilitate the reporting and calculation of the tax.
    “The EPA subpart W revisions blatantly disregard and overstep even the partisan mandates of the IRA, and would excessively increase the tax burden on American energy under this natural gas tax. The revised emission factors with its subpart W reporting requirements make broad assumptions about oil and gas operations and technology that will lead to inaccurate reporting for many owners and operators.
    “The rule would not only radically expand the scope of emissions required to be reported by each facility under the greenhouse gas reporting program, but it also excessively expands the number of facilities that are covered by subpart W, and consequently, responsible to pay the natural gas tax.
    “Due to this uninformed and artificial overestimate of U.S. methane emissions, some smaller operators, who were once below the waste emissions threshold, are now at risk of seeing their reported methane emissions inflated, and owe large sums under the natural gas tax. If not repealed, this rule will arbitrarily increase the cost and burden of reporting under subpart W, motivated by the Democrats’ interest in growing the revenues generated by their natural gas tax.
    “This will make it even more difficult and expensive to produce, transport, and consume American natural gas, and in turn, will hurt both American families who rely on the energy, and the environment of the communities that we live.
    “It’s important that we note that our efforts today works in tandem with this Chamber’s recently passed budget resolution. As Chairman of the Environment and Public Works Committee, I have long intended to stop the natural gas tax, and we will continue to pursue this through the reconciliation process.
    “Today’s vote on the CRA provides all senators the opportunity to put our vote on record after witnessing the Biden EPA’s bait and switch on the implementation of this misguided policy.
    “I encourage my colleagues to support the CRA that is central to our mission of American energy dominance, and rejects this tax that will bolster our adversaries, increase energy costs on American families, and put our energy future at risk.”

    MIL OSI USA News

  • MIL-OSI Canada: B.C. will strengthen biofuel industry with Canadian-content requirements

    Source: Government of Canada regional news

    The Province is taking action to strengthen British Columbia’s energy resilience and support local biofuel producers, ensuring cleaner transportation fuels and greater energy security for people in B.C.

    “British Columbians deserve a reliable, sustainable and Canadian fuel supply,” said Adrian Dix, Minister of Energy and Climate Solutions. “By increasing the Canadian biofuel content in our transportation fuels, we will support local producers, protect jobs and reduce our dependence on foreign energy. This action reflects our commitment to cleaner energy, economic growth and a resilient future for British Columbians.”

    B.C. and Canadian biofuel producers have long felt the impact of the competitive advantage American producers have over Canadian producers because of U.S. subsidies, which have increased under the U.S. Inflation Reduction Act.

    To support B.C. and Canadian biofuel producers, protect local jobs throughout the supply chain and strengthen British Columbia’s energy security, the Province is making key amendments to regulations under the Low Carbon Fuels Act that prioritize the inclusion of Canadian biofuels in B.C.’s transportation fuels. This action will stabilize the biofuel market and support B.C. companies such as Tidewater Renewables in Prince George, Parkland in Burnaby and Consolidated Biofuels in Delta.

    “We welcome the Government of B.C.’s changes to the Low Carbon Fuels Act and the commitment to strengthen the Canadian biofuel sector,” said Jeremy Baines, president and CEO, Tidewater Renewables. “This is a good first step in levelling the playing field with imported biofuels that take advantage of overlapping foreign and Canadian policies, and moving toward an economically viable Canadian renewable fuel industry. Tidewater is committed to being a leader in the energy transition, continuing to develop made-in-B.C. energy solutions, creating good-paying jobs in British Columbia and continuing to supply low-carbon fuels, helping British Columbia and Canada meet emission-reduction targets.”

    Effective Jan. 1, 2026, the minimum 5% renewable-fuel requirement for gasoline must be met with eligible renewable fuels produced in Canada. The renewable-fuel requirement for diesel is 4% and will immediately be increased to 8%. Beginning April 1, 2025, the renewable content of diesel fuel must be produced in Canada.

    The Province has been working closely with B.C. biofuel producers and suppliers to develop an approach that supports the entire industry and limits price impacts. This aligns with the Province’s commitment to sustainability and competitiveness, balancing environmental goals with economic development, signalling B.C.’s leadership in advancing a cleaner and more resilient energy future.

    Quotes:

    Dan Treleaven, chief executive officer, Consolidated Biofuels Ltd. –

    “This news is welcome support for local homegrown biofuel producers. Securing and growing local production reduces reliance on imports, while maintaining one of the most progressive carbon-reduction programs in Canada.”

    Mark Zacharias, executive director, Clean Energy Canada –

    “We are pleased to see today’s amendments to the Low Carbon Fuels Regulation. These changes will provide certainty to B.C. and Canadian biofuel producers, while connecting the Canadian biofuel supply chain and supporting the province’s clean-energy economy. In the face of potential U.S. tariffs, these changes will create jobs here in B.C., while doing our part for the climate.”

    Learn More:

    British Columbia’s Low Carbon Fuel Standard:
    https://www2.gov.bc.ca/gov/content/industry/electricity-alternative-energy/transportation-energies/renewable-low-carbon-fuels

    A backgrounder follows.

    MIL OSI Canada News

  • MIL-OSI Security: Felon In Possession Of Machinegun And Straw Purchaser Are Sentenced

    Source: Office of United States Attorneys

    CHARLOTTE, N.C. – A Charlotte man who illegally possessed a machinegun and a straw purchaser of firearms were sentenced today, announced Lawrence J. Cameron, Acting U.S. Attorney for the Western District of North Carolina. Keon Deangelo Steele, 20, was sentenced to 41 months in prison followed by three years of supervised release. Steele’s girlfriend, Anna Micaiah Denise Mack, 22, also of Charlotte, was ordered to serve 24 months on probation under court supervision. 

    Bennie Mims, Special Agent in Charge of the U.S. Bureau of Alcohol, Tobacco, Firearms and Explosives (ATF), Charlotte Field Division, and Chief Johnny Jennings of the Charlotte Mecklenburg Police Department (CMPD), join Acting U.S. Attorney Cameron in making today’s announcement.

    According to court documents and court proceedings, between May and June 2023, Steele sold multiple firearms to undercover officers. Specifically, on July 6, 2023, Steele communicated to an undercover officer that he had two firearms and two Glock switches for sale. A Glock switch is the common name for an illegal device that coverts a conventional firearm into a machinegun. Law enforcement arrived at the meeting location and observed Steele and Mack waiting inside a vehicle. The defendants were arrested and taken into custody. Law enforcement also searched the vehicle and found a backpack that contained a Glock 42, .40 caliber pistol outfitted with a Glock switch, and an additional Glock switch.

    During the investigation, law enforcement determined that, on June 13, 2023, Mack purchased two firearms, a Glock 22 and a Glock 48, from a federal firearms dealer in Gastonia. Mack completed ATF Form 4473 in connection with the firearms purchases. As Mack later admitted in court, she lied on the form, falsely representing that she was the actual transferee/buyer of the firearms when, in fact, she was buying the firearms for Steele. Court records show that Mack straw purchased at least seven firearms for Steele within a span of a few weeks.

    On June 27, 2024, Steele pleaded guilty to possession of a machinegun. On April 4, 2024, Mack pleaded guilty to making a false statement during the purchase of a firearm.

    Acting U.S. Attorney Cameron thanked the ATF and CMPD for leading the investigation.

    Assistant U.S. Attorney Brandon Boykin of the U.S. Attorney’s Office in Charlotte prosecuted the case.

    The U.S. Attorney’s Office reminds the public that purchasing a gun for someone who is prohibited by law from possessing one, or for someone who does not want his or her name associated with the transaction, is a “straw purchase,” a federal crime punishable by up to 10 years in prison and a fine of up to $250,000. For more information on what you can do to ensure that you do not knowingly or unknowingly participate in a straw purchase, contact your local ATF office or call 1-800-ATF-GUNS.

     

    MIL Security OSI

  • MIL-OSI Security: Armed Drug Trafficker Is Sentenced To 10 Years in Prison

    Source: United States Bureau of Alcohol Tobacco Firearms and Explosives (ATF)

    CHARLOTTE, N.C. – Bryan Torres, 24, of Cherryville, N.C., was sentenced today to 10 years in prison and four years of supervised release on drug and gun charges, announced Lawrence J. Cameron, Acting U.S. Attorney for the Western District of North Carolina.

    According to court documents and court proceedings, between October 2022 to January 2023, Torres engaged in drug trafficking in Gaston County. During the investigation, law enforcement conducted multiple controlled purchases of methamphetamine, over 250 fentanyl pills, powder fentanyl, heroin, and other substances from the defendant. Torres was armed during at least one drug transaction. On February 2, 2023, a search warrant was executed at Torres’s residence. Investigators seized from the residence five firearms and ammunition, and additional amounts of methamphetamine and fentanyl.

    On February 29, 2024, Torres pleaded guilty to distribution of methamphetamine and possession of a firearm by a convicted felon. He will remain in federal custody until he is transferred to the custody of the Federal Bureau of Prisons upon designation of a federal facility.

    The investigation was jointly conducted by the Drug Enforcement Administration, the Bureau of Alcohol, Tobacco, Firearms and Explosives, Homeland Security Investigations, the Cherryville Police Department, and the Gaston County Police Department.

    The U.S. Attorney’s Office in Charlotte prosecuted the case. 

    This case is part of Project Safe Neighborhoods (PSN), a program bringing together all levels of law enforcement and the communities they serve to reduce violent crime and gun violence, and to make our neighborhoods safer for everyone. For more information about PSN in the Western District, please visit our website.

     

    MIL Security OSI

  • MIL-OSI Europe: New action plan to lower energy costs for European citizens and businesses

    Source: European Union 2

    High energy costs are hurting EU citizens and businesses. The Affordable Energy Action Plan sets out concrete measures to lower costs, complete the Energy Union, attract investments, and be better prepared for potential energy crises, to save €260 billion annually on energy by 2040.

    MIL OSI Europe News

  • MIL-OSI Europe: Written question – EU Energy Platform and the exclusion of non-corporate members – E-000723/2025

    Source: European Parliament

    Question for written answer  E-000723/2025
    to the Commission
    Rule 144
    Nikolaos Anadiotis (NI)

    The EU Energy Platform has been criticised for its controversial Industry Advisory Group (IAG), which includes corporate members from the natural gas sector but excludes non-corporate stakeholders such as civil society organisations. This lack of inclusiveness raises concerns about transparency and the undue influence of corporate interests in shaping critical energy policies that affect the wider public.

    The recent decision of the European Ombudsman[1] underlined the inappropriateness of IAG’s current composition, highlighting the over-representation of natural gas lobbies. This imbalance undermines the credibility of the platform and calls into question the EU’s commitment to fair and balanced energy policies. The exclusion of non-corporate members distorts the decision-making process, putting climate targets at risk.

    In light of this:

    • 1.What measures does the Commission intend to take to address the exclusion of non-corporate members from this group? Is there a timetable for the inclusion of a wider range of stakeholders?
    • 2.How does the Commission intend to ensure that energy transition policies are not disproportionately influenced by corporate interests, in particular those related to fossil fuels?

    Submitted: 17.2.2025

    • [1] https://corporateeurope.org/en/2024/09/eu-ombudsman-ruling-shows-gas-industry-advisory-group-not-fit-purpose-time-scrap-it
    Last updated: 27 February 2025

    MIL OSI Europe News

  • MIL-OSI Europe: Meeting of 29-30 January 2025

    Source: European Central Bank

    Account of the monetary policy meeting of the Governing Council of the European Central Bank held in Frankfurt am Main on Wednesday and Thursday, 29-30 January 2025

    27 February 2025

    1. Review of financial, economic and monetary developments and policy options

    Financial market developments

    Ms Schnabel noted that the financial market developments observed in the euro area after October 2024 had reversed since the Governing Council’s previous monetary policy meeting on 11-12 December 2024. The US presidential election in November had initially led to lower euro area bond yields and equity prices. Since the December monetary policy meeting, however, both risk-free yields and risk asset prices had moved substantially higher and had more than made up their previous declines. A less gloomy domestic macroeconomic outlook and an increase in the market’s outlook for inflation in the euro area on the back of higher energy prices had led investors to expect the ECB to proceed with a more gradual rate easing path.

    A bounce-back of euro area risk appetite had supported equity and corporate bond prices and had contained sovereign bond spreads. While the euro had also rebounded recently against the US dollar, it remained significantly weaker than before the US election.

    In euro money markets the year-end had been smooth. Money market conditions at the turn of the year had turned out to be more benign than anticipated, with a decline in repo rates and counterparties taking only limited recourse to the ECB’s standard refinancing operations.

    In the run-up to the US election and in its immediate aftermath, ten-year overnight index swap (OIS) rates in the euro area and the United States had decoupled, reflecting expectations of increasing macroeconomic divergence. However, since the Governing Council’s December monetary policy meeting, long-term interest rates had increased markedly in both the euro area and the United States. An assessment of the drivers of euro area long-term rates showed that both domestic and US factors had pushed yields up. But domestic factors – expected tighter ECB policy and a less gloomy euro area macroeconomic outlook – had mattered even more than US spillovers. These factors included a reduction in perceived downside risks to economic growth from tariffs and a stronger than anticipated January flash euro area Purchasing Managers’ Index (PMI).

    Taking a longer-term perspective on ten-year rates, since October 2022, when inflation had peaked at 10.6% and policy rates had just returned to positive territory, nominal OIS rates and their real counterparts had been broadly trending sideways. From that perspective, the recent uptick was modest and could be seen as a mean reversion to the new normal.

    A decomposition of the change in ten-year OIS rates since the start of 2022 showed that the dominant driver of persistently higher long-term yields compared with the “low-for-long” interest rate and inflation period had been the sharp rise in real rate expectations. A second major driver had been an increase in real term premia in the context of quantitative tightening. This increase had occurred mainly in 2022. Since 2023, real term premia had broadly trended sideways albeit with some volatility. Hence, the actual reduction of the ECB’s balance sheet had elicited only mild upward pressure on term premia. From a historical perspective, despite their recent increase, term premia in the euro area remained compressed compared with the pre-quantitative easing period.

    Since the December meeting, investors had revised up their expectations for HICP inflation (excluding tobacco) for 2025. Current inflation fixings (swap contracts linked to specific monthly releases in year-on-year euro area HICP inflation excluding tobacco) for this year stood above the 2% target. Higher energy prices had been a key driver of the reassessment of near-term inflation expectations. Evidence from option prices, calculated under the assumption of risk neutrality, suggested that the risk to inflation in financial markets had become broadly balanced, with the indicators across maturities having shifted discernibly upwards. Recent survey evidence suggested that risks of inflation overshooting the ECB’s target of 2% had resurfaced. Respondents generally saw a bigger risk of an inflation overshoot than of an inflation undershoot.

    The combination of a less gloomy macroeconomic outlook and stronger price pressures had led markets to reassess the ECB’s expected monetary policy path. Market pricing suggested expectations of a more gradual easing cycle with a higher terminal rate, pricing out the probability of a cut larger than 25 basis points at any of the next meetings. Overall, the size of expected cuts to the deposit facility rate in 2025 had dropped by around 40 basis points, with the end-year rate currently seen at 2.08%. Market expectations for 2025 stood above median expectations in the Survey of Monetary Analysts. Survey participants continued to expect a faster easing cycle, with cuts of 25 basis points at each of the Governing Council’s next four monetary policy meetings.

    The Federal Funds futures curve had continued to shift upwards, with markets currently expecting between one and two 25 basis point cuts by the end of 2025. The repricing of front-end yields since the Governing Council’s December meeting had been stronger in the euro area than in the United States. This would typically also be reflected in foreign exchange markets. However, the EUR/USD exchange rate had recently decoupled from interest rates, as the euro had initially continued to depreciate despite a narrowing interest rate differential, before recovering more recently. US dollar currency pairs had been affected by the US Administration’s comments, which had put upward pressure on the US dollar relative to trading partners’ currencies.

    Euro area equity markets had outperformed their US counterparts in recent weeks. A model decomposition using a standard dividend discount model for the euro area showed that rising risk-free yields had weighed significantly on euro area equity prices. However, this had been more than offset by higher dividends, and especially a compression of the risk premium, indicating improved investor risk sentiment towards the euro area, as also reflected in other risk asset prices. Corporate bond spreads had fallen across market segments, including high-yield bonds. Sovereign spreads relative to the ten-year German Bund had remained broadly stable or had even declined slightly. Relative to OIS rates, the spreads had also remained broadly stable. The Bund-OIS spread had returned to levels observed before the Eurosystem had started large-scale asset purchases in 2015, suggesting that the scarcity premium in the German government bond market had, by and large, normalised.

    Standard financial condition indices for the euro area had remained broadly stable since the December meeting. The easing impulse from higher equity prices had counterbalanced the tightening impulse stemming from higher short and long-term rates. In spite of the bounce-back in euro area real risk-free interest rates, the yield curve remained broadly within neutral territory.

    The global environment and economic and monetary developments in the euro area

    Starting with inflation in the euro area, Mr Lane noted that headline inflation, as expected, had increased to 2.4% in December, up from 2.2% in November. The increase primarily reflected a rise in energy inflation from -2.0% in November to 0.1% in December, due mainly to upward base effects. Food inflation had edged down to 2.6%. Core inflation was unchanged at 2.7% in December, with a slight decline in goods inflation, which had eased to 0.5%, offset by services inflation rising marginally to 4.0%.

    Developments in most indicators of underlying inflation had been consistent with a sustained return of inflation to the medium-term inflation target. The Persistent and Common Component of Inflation (PCCI), which had the best predictive power of any underlying inflation indicator for future headline inflation, had continued to hover around 2% in December, indicating that headline inflation was set to stabilise around the ECB’s inflation target. Domestic inflation, which closely tracked services inflation, stood at 4.2%, staying well above all the other indicators in December. However, the PCCI for services, which should act as an attractor for services and domestic inflation, had fallen to 2.3%.

    The anticipation of a downward shift in services inflation in the coming months also related to an expected deceleration in wage growth this year. Wages had been adjusting to the past inflation surge with a substantial delay, but the ECB wage tracker and the latest surveys pointed to moderation in wage pressures. According to the latest results of the Survey on the Access to Finance of Enterprises, firms expected wages to grow by 3.3% on average over the next 12 months, down from 3.5% in the previous survey round and 4.5% in the equivalent survey this time last year. This assessment was shared broadly across the forecasting community. Consensus Economics, for example, foresaw a decline in wage growth of about 1 percentage point between 2024 and 2025.

    Most measures of longer-term inflation expectations continued to stand at around 2%, despite an uptick over shorter horizons. Although, according to the Survey on the Access to Finance of Enterprises, the inflation expectations of firms had stabilised at 3% across horizons, the expectations of larger firms that were aware of the ECB’s inflation target showed convergence towards 2%. Consumer inflation expectations had edged up recently, especially for the near term. This could be explained at least partly by their higher sensitivity to actual inflation. There had also been an uptick in the near-term inflation expectations of professionals – as captured by the latest vintages of the Survey of Professional Forecasters and the Survey of Monetary Analysts, as well as market-based measures of inflation compensation. Over longer horizons, though, the inflation expectations of professional forecasters remained stable at levels consistent with the medium-term target of 2%.

    Headline inflation should fluctuate around its current level in the near term and then settle sustainably around the target. Easing labour cost pressures and the continuing impact of past monetary policy tightening should support the convergence to the inflation target.

    Turning to the international environment, global economic activity had remained robust around the turn of the year. The global composite PMI had held steady at 53.0 in the fourth quarter of 2024, owing mainly to the continued strength in the services sector that had counterbalanced weak manufacturing activity.

    Since the Governing Council’s previous meeting, the euro had remained broadly stable in nominal effective terms (+0.5%) and against the US dollar (+0.2%). Oil prices had seen a lot of volatility, but the latest price, at USD 78 per barrel, was only around 3½% above the spot oil price at the cut-off date for the December Eurosystem staff projections and 2.6% above the spot price at the time of the last meeting. With respect to gas prices, the spot price stood at €48 per MWh, 2.7% above the level at the cut-off date for the December projections and 6.8% higher than at the time of the last meeting.

    Following a comparatively robust third quarter, euro area GDP growth had likely moderated again in the last quarter of 2024 – confirmed by Eurostat’s preliminary flash estimate released on 30 January at 11:00 CET, with a growth rate of 0% for that quarter, later revised to 0.1%. Based on currently available information, private consumption growth had probably slowed in the fourth quarter amid subdued consumer confidence and heightened uncertainty. Housing investment had not yet picked up and there were no signs of an imminent expansion in business investment. Across sectors, industrial activity had been weak in the summer and had softened further in the last few months of 2024, with average industrial production excluding construction in October and November standing 0.4% below its third quarter level. The persistent weakness in manufacturing partly reflected structural factors, such as sectoral trends, losses in competitiveness and relatively high energy prices. However, manufacturing firms were also especially exposed to heightened uncertainty about global trade policies, regulatory costs and tight financing conditions. Service production had grown in the third quarter, but the expansion had likely moderated in the fourth quarter.

    The labour market was robust, with the unemployment rate falling to a historical low of 6.3% in November – with the figure for December (6.3%) and a revised figure for November (6.2%) released later on the morning of 30 January. However, survey evidence and model estimates suggested that euro area employment growth had probably softened in the fourth quarter.

    The fiscal stance for the euro area was now expected to be balanced in 2025, as opposed to the slight tightening foreseen in the December projections. Nevertheless, the current outlook for the fiscal stance was subject to considerable uncertainty.

    The euro area economy was set to remain subdued in the near term. The flash composite output PMI for January had ticked up to 50.2 driven by an improvement in manufacturing output, as the rate of contraction had eased compared with December. The January release had been 1.7 points above the average for the fourth quarter, but it still meant that the manufacturing sector had been in contractionary territory for nearly two years. The services business activity index had decelerated slightly to 51.4 in January, staying above the average of 50.9 in the fourth quarter of 2024 but still below the figure of 52.1 for the third quarter.

    Even with a subdued near-term outlook, the conditions for a recovery remained in place. Higher incomes should allow spending to rise. More affordable credit should also boost consumption and investment over time. And if trade tensions did not escalate, exports should also support the recovery as global demand rose.

    Turning to the monetary and financial analysis, bond yields, in both the euro area and globally, had increased significantly since the last meeting. At the same time, the ECB’s past interest rate cuts were gradually making it less expensive for firms and households to borrow. Lending rates on bank loans to firms and households for new business had continued to decline in November. In the same period, the cost of borrowing for firms had decreased by 15 basis points to 4.52% and stood 76 basis points below the cyclical peak observed in October 2023. The cost of issuing market-based debt had remained at 3.6% in November 2024. Mortgage rates had fallen by 8 basis points to 3.47% since October, 56 basis points lower than their peak in November 2023. However, the interest rates on existing corporate and household loan books remained high.

    Financing conditions remained tight. Although credit was expanding, lending to firms and households was subdued relative to historical averages. Annual growth in bank lending to firms had risen to 1.5% in December, up from 1% in November, as a result of strong monthly flows. But it remained well below the 4.3% historical average since January 1999. By contrast, growth in corporate debt securities issuance had moderated to 3.2% in annual terms, from 3.6% in November. This suggested that firms had substituted market-based long-term financing for bank-based borrowing amid tightening market conditions and in advance of increasing redemptions of long-term corporate bonds. Mortgage lending had continued to rise gradually but remained muted overall, with an annual growth rate of 1.1% in December after 0.9% in November. This was markedly below the long-term average of 5.1%.

    According to the latest euro area bank lending survey, the demand for loans by firms had increased slightly in the last quarter. At the same time, credit standards for loans to firms had tightened again, having broadly stabilised over the previous four quarters. This renewed tightening of credit standards for firms had been motivated by banks seeing higher risks to the economic outlook and their lower tolerance for taking on credit risk. This finding was consistent with the results of the Survey on the Access to Finance of Enterprises, in which firms had reported a small decline in the availability of bank loans and tougher non-rate lending conditions. Turning to households, the demand for mortgages had increased strongly as interest rates became more attractive and prospects for the property market improved. Credit standards for housing loans remained unchanged overall.

    Monetary policy considerations and policy options

    In summary, the disinflation process remained well on track. Inflation had continued to develop broadly in line with the staff projections and was set to return to the 2% medium-term target in the course of 2025. Most measures of underlying inflation suggested that inflation would settle around the target on a sustained basis. Domestic inflation remained high, mostly because wages and prices in certain sectors were still adjusting to the past inflation surge with a substantial delay. However, wage growth was expected to moderate and lower profit margins were partially buffering the impact of higher wage costs on inflation. The ECB’s recent interest rate cuts were gradually making new borrowing less expensive for firms and households. At the same time, financing conditions continued to be tight, also because monetary policy remained restrictive and past interest rate hikes were still being transmitted to the stock of credit, with some maturing loans being rolled over at higher rates. The economy was still facing headwinds, but rising real incomes and the gradually fading effects of restrictive monetary policy should support a pick-up in demand over time.

    Concerning the monetary policy decision at this meeting, it was proposed to lower the three key ECB interest rates by 25 basis points. In particular, lowering the deposit facility rate – the rate through which the ECB steered the monetary policy stance – was justified by the updated assessment of the inflation outlook, the dynamics of underlying inflation and the strength of monetary policy transmission. The alternative – maintaining the deposit facility rate at the current level of 3.00% – would excessively dampen demand and therefore be inconsistent with the set of rate paths that best ensured inflation stabilised sustainably at the 2% medium-term target.

    Looking to the future, it was prudent to maintain agility, so as to be able to adjust the stance as appropriate on a meeting-by-meeting basis, and not to pre-commit to any particular rate path. In particular, monetary easing might proceed more slowly in the event of upside shocks to the inflation outlook and/or to economic momentum. Equally, in the event of downside shocks to the inflation outlook and/or to economic momentum, monetary easing might proceed more quickly.

    2. Governing Council’s discussion and monetary policy decisions

    Economic, monetary and financial analyses

    As regards the external environment, incoming data since the Governing Council’s previous monetary policy meeting had signalled robust global activity in the fourth quarter of 2024, with divergent paths across economies and an uncertain outlook for global trade. The euro had been broadly stable and energy commodity prices had increased. It was underlined that gas prices were currently over 60% higher than in 2024 because the average temperature during the previous winter had been very mild, whereas this winter was turning out to be considerably colder. This suggested that demand for gas would remain strong, as reserves needed to be replenished ahead of the next heating season, keeping gas prices high for the remainder of the year. In other commodity markets, metal prices were stable – subdued by weak activity in China and the potential negative impact of US tariffs – while food prices had increased.

    Members concurred that the outlook for the international economy remained highly uncertain. The United States was the only advanced economy that was showing sustained growth dynamics. Global trade might be hit hard if the new US Administration were to implement the measures it had announced. The challenges faced by the Chinese economy also remained visible in prices. Chinese inflation had declined further on the back of weak domestic demand. In this context, it was pointed out that, no matter how severe the new US trade measures turned out to be, the euro area would be affected either indirectly by disinflationary pressures or directly, in the event of retaliation, by higher inflation. In particular, if China were to redirect trade away from the United States and towards the euro area, this would make it easier to achieve lower inflation in the euro area but would have a negative impact on domestic activity, owing to greater international competition.

    With regard to economic activity in the euro area, it was widely recognised that incoming data since the last Governing Council meeting had been limited and, ahead of Eurostat’s indicator of GDP for the fourth quarter of 2024, had not brought any major surprises. Accordingly, it was argued that the December staff projections remained the most likely scenario, with the downside risks to growth that had been identified not yet materialising. The euro area economy had seen some encouraging signs in the January flash PMIs, although it had to be recognised that, in these uncertain times, hard data seemed more important than survey results. The outcome for the third quarter had surprised on the upside, showing tentative signs of a pick-up in consumption. Indications from the few national data already available for the fourth quarter pointed to a positive contribution from consumption. Despite all the prevailing uncertainties, it was still seen as plausible that, within a few quarters, there would be a consumption-driven recovery, with inflation back at target, policy rates broadly at neutral levels and continued full employment. Moreover, the latest information on credit flows and lending rates suggested that the gradual removal of monetary restrictiveness was already being transmitted to the economy, although the past tightening measures were still exerting lagged effects.

    The view was also expressed that the economic outlook in the December staff projections had likely been too optimistic and that there were signs of downside risks materialising. The ECB’s mechanical estimates pointed to very weak growth around the turn of the year and, compared with other institutions, the Eurosystem’s December staff projections had been among the most optimistic. Attention was drawn to the dichotomy between the performance of the two largest euro area economies and that of the rest of the euro area, which was largely due to country-specific factors.

    Recent forecasts from the Survey of Professional Forecasters, the Survey of Monetary Analysts and the International Monetary Fund once again suggested a downward revision of euro area economic growth for 2025 and 2026. Given this trend of downward revisions, doubts were expressed about the narrative of a consumption-driven economic recovery in 2025. Moreover, the December staff projections had not directly included the economic impact of possible US tariffs in the baseline, so it was hard to be optimistic about the economic outlook. The outlook for domestic demand had deteriorated, as consumer confidence remained weak and investment was not showing any convincing signs of a pick-up. The contribution from foreign demand, which had been the main driver of growth over the past two years, had also been declining since last spring. Moreover, uncertainty about potential tariffs to be imposed by the new US Administration was weighing further on the outlook. In the meantime, labour demand was losing momentum. The slowdown in economic activity had started to affect temporary employment: these jobs were always the first to disappear as the labour market weakened. At the same time, while the labour market had softened over recent months, it continued to be robust, with the unemployment rate staying low, at 6.3% in December. A solid job market and higher incomes should strengthen consumer confidence and allow spending to rise.

    There continued to be a strong dichotomy between a more dynamic services sector and a weak manufacturing sector. The services sector had remained robust thus far, with the PMI in expansionary territory and firms reporting solid demand. The extent to which the weakness in manufacturing was structural or cyclical was still open to debate, but there was a growing consensus that there was a large structural element, as high energy costs and strict regulation weighed on firms’ competitiveness. This was also reflected in weak export demand, despite the robust growth in global trade. All these factors also had an adverse impact on business investment in the industrial sector. This was seen as important to monitor, as a sustainable economic recovery also depended on a recovery in investment, especially in light of the vast longer-term investment needs of the euro area. Labour markets showed a dichotomy similar to the one observed in the economy more generally. While companies in the manufacturing sector were starting to lay off workers, employment in the services sector was growing. At the same time, concerns were expressed about the number of new vacancies, which had continued to fall. This two-speed economy, with manufacturing struggling and services resilient, was seen as indicating only weak growth ahead, especially in conjunction with the impending geopolitical tensions.

    Against this background, geopolitical and trade policy uncertainty was likely to continue to weigh on the euro area economy and was not expected to recede anytime soon. The point was made that if uncertainty were to remain high for a prolonged period, this would be very different from a shorter spell of uncertainty – and even more detrimental to investment. Therefore the economic recovery was unlikely to receive much support from investment for some time. Indeed, excluding Ireland, euro area business investment had been contracting recently and there were no signs of a turnaround. This would limit investment in physical and human capital further, dragging down potential output in the medium term. However, reference was also made to evidence from psychological studies, which suggested that the impact of higher uncertainty might diminish over time as agents’ perceptions and behaviour adapted.

    In this context, a remark was made on the importance of monetary and fiscal policies for enabling the economy to return to its previous growth path. Economic policies were meant to stabilise the economy and this stabilisation sometimes required a long time. After the pandemic, many economic indicators had returned to their pre-crisis levels, but this had not yet implied a return to pre-crisis growth paths, even though the output gap had closed in the meantime. A question was raised on bankruptcies, which were increasing in the euro area. To the extent that production capacity was being destroyed, the output gap might be closing because potential output growth was declining, and not because actual growth was increasing. However, it was also noted that bankruptcies were rising from an exceptionally low level and developments remained in line with historical regularities.

    Members reiterated that fiscal and structural policies should make the economy more productive, competitive and resilient. They welcomed the European Commission’s Competitiveness Compass, which provided a concrete roadmap for action. It was seen as crucial to follow up, with further concrete and ambitious structural policies, on Mario Draghi’s proposals for enhancing European competitiveness and on Enrico Letta’s proposals for empowering the Single Market. Governments should implement their commitments under the EU’s economic governance framework fully and without delay. This would help bring down budget deficits and debt ratios on a sustained basis, while prioritising growth-enhancing reforms and investment.

    Against this background, members assessed that the risks to economic growth remained tilted to the downside. Greater friction in global trade could weigh on euro area growth by dampening exports and weakening the global economy. Lower confidence could prevent consumption and investment from recovering as fast as expected. This could be amplified by geopolitical risks, such as Russia’s unjustified war against Ukraine and the tragic conflict in the Middle East, which could disrupt energy supplies and further weigh on global trade. Growth could also be lower if the lagged effects of monetary policy tightening lasted longer than expected. It could be higher if easier financing conditions and falling inflation allowed domestic consumption and investment to rebound faster.

    On price developments, members concurred with Mr Lane’s assessment that the incoming data confirmed disinflation was on track and that a return to the target in the course of 2025 was within reach. On the nominal side, there had been no major data surprises since the December Governing Council meeting and inflation expectations remained well anchored. Recent inflation data had been slightly below the December staff projections, but energy prices were on the rise. These two elements by and large offset one another. The inflation baseline from the December staff projections was therefore still a realistic scenario, indicating that inflation was on track to converge towards target in the course of 2025. Nevertheless, it was recalled that, for 2027, the contribution from the new Emissions Trading System (ETS2) assumptions was mechanically pushing the Eurosystem staff inflation projections above 2%. Furthermore, the market fixings for longer horizons suggested that there was a risk of undershooting the inflation target in 2026 and 2027. It was remarked that further downside revisions to the economic outlook would tend to imply a negative impact on the inflation outlook and an undershooting of inflation could not be ruled out.

    At the same time, the view was expressed that the risks to the December inflation projections were now tilted to the upside, so that the return to the 2% inflation target might take longer than previously expected. Although it was acknowledged that the momentum in services inflation had eased in recent months, the outlook for inflation remained heavily dependent on the evolution of services inflation, which accounted for around 75% of headline inflation. Services inflation was therefore widely seen as the key inflation component to monitor during the coming months. Services inflation had been stuck at roughly 4% for more than a year, while core inflation had also proven sluggish after an initial decline, remaining at around 2.7% for nearly a year. This raised the question as to where core inflation would eventually settle: in the past, services inflation and core inflation had typically been closely connected. It was also highlighted that, somewhat worryingly, the inflation rate for “early movers” in services had been trending up since its trough in April 2024 and was now standing well above the “followers” and the “late movers” at around 4.6%. This partly called into question the narrative behind the expected deceleration in services inflation. Moreover, the January flash PMI suggested that non-labour input costs, including energy and shipping costs, had increased significantly. The increase in the services sector had been particularly sharp, which was reflected in rising PMI selling prices for services – probably also fuelled by the tight labour market. As labour hoarding was a more widespread phenomenon in manufacturing, this implied that a potential pick-up in demand and the associated cyclical recovery in labour productivity would not necessarily dampen unit labour costs in the services sector to the same extent as in manufacturing.

    One main driver of the stickiness in services inflation was wage growth. Although wage growth was expected to decelerate in 2025, it would still stand at 4.5% in the second quarter of 2025 according to the ECB wage tracker. The pass-through of wages tended to be particularly strong in the services sector and occurred over an extended period of time, suggesting that the deceleration in wages might take some time to be reflected in lower services inflation. The forward-looking wage tracker was seen as fairly reliable, as it was based on existing contracts, whereas focusing too much on lagging wage data posed the risk of monetary policy falling behind the curve. This was particularly likely if negative growth risks eventually affected the labour market. Furthermore, a question was raised as to the potential implications for wage pressures of more restrictive labour migration policies.

    Overall, looking ahead there seemed reasons to believe that both services inflation and wage growth would slow down in line with the baseline scenario in the December staff projections. From the current quarter onwards, services inflation was expected to decline. However, in the early months of the year a number of services were set to be repriced, for instance in the insurance and tourism sectors, and there were many uncertainties surrounding this repricing. It was therefore seen as important to wait until March, when two more inflation releases and the new projections would be available, to reassess the inflation baseline as contained in the December staff projections.

    As regards longer-term inflation expectations, members took note of the latest developments in market-based measures of inflation compensation and survey-based indicators. The December Consumer Expectations Survey showed another increase in near-term inflation expectations, with inflation expectations 12 months ahead having already gradually picked up from 2.4% in September to 2.8% in December. Density-based expectations were even higher at 3%, with risks tilted to the upside. According to the Survey on the Access to Finance of Enterprises, firms’ median inflation expectations had also risen to 3%. However it was regarded as important to focus more on the change in inflation expectations than on the level of expectations when interpreting these surveys.

    As regards risks to the inflation outlook, with respect to the market-based measures, the view was expressed that there had been a shift in the balance of risks, pointing to upside risks to the December inflation outlook. In financial markets, inflation fixings for 2025 had shifted above the December short-term projections and inflation expectations had picked up across all tenors. In market surveys, risks of overshooting had resurfaced, with a larger share of respondents in the surveys seeing risks of an overshooting in 2025. Moreover, it was argued that tariffs, their implications for the exchange rate, and energy and food prices posed upside risks to inflation.

    Against this background, members considered that inflation could turn out higher if wages or profits increased by more than expected. Upside risks to inflation also stemmed from the heightened geopolitical tensions, which could push energy prices and freight costs higher in the near term and disrupt global trade. Moreover, extreme weather events, and the unfolding climate crisis more broadly, could drive up food prices by more than expected. By contrast, inflation might surprise on the downside if low confidence and concerns about geopolitical events prevented consumption and investment from recovering as fast as expected, if monetary policy dampened demand by more than expected, or if the economic environment in the rest of the world worsened unexpectedly. Greater friction in global trade would make the euro area inflation outlook more uncertain.

    Turning to the monetary and financial analysis, members broadly agreed with the assessment presented by Ms Schnabel and Mr Lane. It was noted that market interest rates in the euro area had risen since the Governing Council’s December monetary policy meeting, partly mirroring higher rates in global financial markets. Overall, financial conditions had been broadly stable, with higher short and long-term interest rates being counterbalanced by strong risk asset markets and a somewhat weaker exchange rate.

    Long-term interest rates had been rising more substantially than short-term ones, resulting in a steepening of the yield curve globally since last autumn. At the same time, it was underlined that the recent rise in long-term bond yields did not appear to be particularly striking when looking at developments over a longer time period. Over the past two years long-term rates had remained remarkably stable, especially when taking into account the pronounced variation in policy rates.

    The dynamics of market rates since the December Governing Council meeting had been similar on both sides of the Atlantic. This reflected higher term premia as well as a repricing of rate expectations. However, the relative contributions of the underlying drivers differed. In the United States, one factor driving up market interest rates had been an increase in inflation expectations, combined with the persistent strength of the US economy as well as concerns over prospects of higher budget deficits. This had led markets to price out some of the rate cuts that had been factored into the rate expectations prevailing before the Federal Open Market Committee meeting in December 2024. Uncertainty regarding the policies implemented by the new US Administration had also contributed to the sell-off in US government bonds. In Europe, term premia accounted for a significant part of the increase in long-term rates, which could be explained by a combination of factors. These included spillovers from the United States, concerns over the outlook for fiscal policy, and domestic and global policy uncertainty more broadly. Attention was also drawn to the potential impact of tighter monetary policy in Japan, the world’s largest creditor nation, with Japanese investors likely to start shifting their funds away from overseas investments towards domestic bond markets in response to rising yields.

    The passive reduction in the Eurosystem’s balance sheet, as maturing bonds were no longer reinvested, was also seen as exerting gradual upward pressure on term premia over longer horizons, although this had not been playing a significant role – especially not in developments since the last meeting. The reduction had been indicated well in advance and had already been priced in, to a significant extent, at the time the phasing out of reinvestment had been announced. The residual Eurosystem portfolios were still seen to be exerting substantial downside pressure on longer-term sovereign yields as compared with a situation in which asset holdings were absent. It was underlined that, while declining central bank holdings did affect financial conditions, quantitative tightening was operating gradually and smoothly in the background.

    In the context of the discussion on long-term yields, attention was drawn to the possibility that rising yields might also lead to financial stability risks, especially in view of the high level of valuations and leverage in the world economy. A further financial stability risk related to the prospect of a more deregulated financial system in the United States, including in the realm of crypto-assets. This could allow risks to build up in the years to come and sow the seeds of a future financial crisis.

    Turning to financing conditions, past interest rate cuts were gradually making it less expensive for firms and households to borrow. For new business, rates on bank loans to firms and households had continued to decline in November. However, the interest rates on existing loans remained high, and financing conditions remained tight.

    Although credit was expanding, lending to firms and households was subdued relative to historical averages. Growth in bank lending to firms had risen to 1.5% in December in annual terms, up from 1.0% in November. Mortgage lending had continued to rise gradually but remained muted overall, with an annual growth rate of 1.1% in December following 0.9% in November. Nevertheless, the increasing pace of loan growth was encouraging and suggested monetary easing was starting to be transmitted through the bank lending channel. Some comfort could also be taken from the lack of evidence of any negative impact on bank lending conditions from the decline in excess liquidity in the banking system.

    The bank lending survey was providing mixed signals, however. Credit standards for mortgages had been broadly unchanged in the fourth quarter, after easing for a while, and banks expected to tighten them in the next quarter. Banks had reported the third strongest increase in demand for mortgages since the start of the survey in 2003, driven primarily by more attractive interest rates. This indicated a turnaround in the housing market as property prices picked up. At the same time, credit standards for consumer credit had tightened in the fourth quarter, with standards for firms also tightening unexpectedly. The tightening had largely been driven by heightened perceptions of economic risk and reduced risk tolerance among banks.

    Caution was advised on overinterpreting the tightening in credit standards for firms reported in the latest bank lending survey. The vast majority of banks had reported unchanged credit standards, with only a small share tightening standards somewhat and an even smaller share easing them slightly. However, it was recalled that the survey methodology for calculating net percentages, which typically involved subtracting a small percentage of easing banks from a small percentage of tightening banks, was an established feature of the survey. Also, that methodology had not detracted from the good predictive power of the net percentage statistic for future lending developments. Moreover, the information from the bank lending survey had also been corroborated by the Survey on the Access to Finance of Enterprises, which had pointed to a slight decrease in the availability of funds to firms. The latter survey was now carried out at a quarterly frequency and provided an important cross-check, based on the perspective of firms, of the information received from banks.

    Turning to the demand for loans by firms, although the bank lending survey had shown a slight increase in the fourth quarter it had remained weak overall, in line with subdued investment. It was remarked that the limited increase in firms’ demand for loans might mean they were expecting rates to be cut further and were waiting to borrow at lower rates. This suggested that the transmission of policy rate cuts was likely to be stronger as the end of the rate-cutting cycle approached. At the same time, it was argued that demand for loans to euro area firms was mainly being held back by economic and geopolitical uncertainty rather than the level of interest rates.

    Monetary policy stance and policy considerations

    Turning to the monetary policy stance, members assessed the data that had become available since the last monetary policy meeting in accordance with the three main elements the Governing Council had communicated in 2023 as shaping its reaction function. These comprised (i) the implications of the incoming economic and financial data for the inflation outlook, (ii) the dynamics of underlying inflation, and (iii) the strength of monetary policy transmission.

    Starting with the inflation outlook, members widely agreed that the incoming data were broadly in line with the medium-term inflation trajectory embedded in the December staff projections. Inflation had been slightly lower than expected in both November and December. The outlook remained heavily dependent on the evolution of services inflation, which had remained close to 4% for more than a year. However, the momentum of services inflation had eased in recent months and a further decrease in wage pressures was anticipated, especially in the second half of 2025. Oil and gas prices had been higher than embodied in the December projections and needed to be closely monitored, but up to now they did not suggest a major change to the baseline in the staff projections.

    Risks to the inflation outlook were seen as two-sided: upside risks were posed by the outlook for energy and food prices, a stronger US dollar and the still sticky services inflation, while a downside risk related to the possibility of growth being lower than expected. There was considerable uncertainty about the effect of possible US tariffs, but the estimated impact on euro area inflation was small and its sign was ambiguous, whereas the implications for economic growth were clearly negative. Further uncertainty stemmed from the possible downside pressures emanating from falling Chinese export prices.

    There was some evidence suggesting a shift in the balance of risks to the upside since December, as reflected, for example, in market surveys showing that the risk of inflation overshooting the target outweighed the risk of an undershooting. Although some of the survey-based inflation expectations as well as market-derived inflation compensation had been revised up slightly, members took comfort from the fact that longer-term measures of inflation expectations remained well anchored at 2%.

    Turning to underlying inflation, members concurred that developments in most measures of underlying inflation suggested that inflation would settle at around the target on a sustained basis. Core inflation had been sticky at around 2.7% for nearly a year but had also turned out lower than projected. A number of measures continued to show a certain degree of persistence, with domestic inflation remaining high and exclusion-based measures proving sticky at levels above 2%. In addition, the translation of wage moderation into a slower rise in domestic prices and unit labour costs was subject to lags and predicated on profit margins continuing their buffering role as well as a cyclical rebound in labour productivity. However, a main cause of stickiness in domestic inflation was services inflation, which was strongly influenced by wage growth, and this was expected to decelerate in the course of 2025.

    As regards the transmission of monetary policy, recent credit dynamics showed that monetary policy transmission was working. Both the past tightening and the subsequent gradual removal of restriction were feeding through to financing conditions, including lending rates and credit flows. It was highlighted that not all demand components had been equally responsive, with, in particular, business investment held back by high uncertainty and structural weaknesses. Companies widely cited having their own funds as a reason for not making loan applications, and the reason for not investing these funds was likely linked to the high levels of uncertainty, rather than to the level of interest rates. Hence low investment was not necessarily a sign of a restrictive monetary policy. At the same time, it was unclear how much of the past tightening was still in the pipeline. Similarly, it would take time for the full effect of recent monetary policy easing to reach the economy, with even variable rate loans typically adjusting with a lag, and the same being true for deposits.

    Monetary policy decisions and communication

    Against this background, all members agreed with the proposal by Mr Lane to lower the three key ECB interest rates by 25 basis points. Lowering the deposit facility rate – the rate through which the monetary policy stance was steered – was justified by the updated assessment of the inflation outlook, the dynamics of underlying inflation and the strength of monetary policy transmission.

    There was a clear case for a further 25 basis point rate cut at the current meeting, and such a step was supported by the incoming data. Members concurred that the disinflationary process was well on track, while the growth outlook continued to be weak. Although the goal had not yet been achieved and inflation was still expected to remain above target in the near term, confidence in a timely and sustained convergence had increased, as both headline and core inflation had recently come in below the ECB projections. In particular, a return of inflation to the 2% target in the course of 2025 was in line with the December staff baseline projections, which were constructed on the basis of an interest rate path that stood significantly below the present level of the forward curve.

    At the same time, it was underlined that high levels of uncertainty, lingering upside risks to energy and food prices, a strong labour market and high negotiated wage increases, as well as sticky services inflation, called for caution. Upside risks could delay a sustainable return to target, while inflation expectations might be more fragile after a long period of high inflation. Firms had also learned to raise their prices more quickly in response to new inflationary shocks. Moreover, the financial market reactions to heightened geopolitical uncertainty or risk aversion often led to an appreciation of the US dollar and might involve spikes in energy prices, which could be detrimental to the inflation outlook.

    Risks to the growth outlook remained tilted to the downside, which typically also implied downside risks to inflation over longer horizons. The outlook for economic activity was clouded by elevated uncertainty stemming from geopolitical tensions, fiscal policy concerns in the euro area and recent global trade frictions associated with potential future actions by the US Administration that might lead to a global economic slowdown. As long as the disinflation process remained on track, policy rates could be brought further towards a neutral level to avoid unnecessarily holding back the economy. Nevertheless, growth risks had not shifted to a degree that would call for an acceleration in the move towards a neutral stance. Moreover, it was argued that greater caution was needed on the size and pace of further rate cuts when policy rates were approaching neutral territory, in view of prevailing uncertainties.

    Lowering the deposit facility rate to 2.75% at the current meeting was also seen as appropriate from a risk-management perspective. On the one hand, it left sufficient optionality to react to the possible emergence of new price pressures. On the other hand, it addressed the risk of falling behind the curve in dialling back restriction and guarded against inflation falling below target.

    Looking ahead, it was regarded as premature for the Governing Council to discuss a possible landing zone for the key ECB interest rates as inflation converged sustainably to target. It was widely felt that even with the current deposit facility rate, it was relatively safe to make the assessment that monetary policy was still restrictive. This was also consistent with the fact that the economy was relatively weak. At the same time, the view was expressed that the natural or neutral rate was likely to be higher than before the pandemic, as the balance between the global demand for and supply of savings had changed over recent years. The main reasons for this were the high and rising global need for investment to deal with the green and digital transitions, the surge in public debt and increasing geopolitical fragmentation, which was reversing the global savings glut and reducing the supply of savings. A higher neutral rate implied that, with a further reduction in policy rates at the present meeting, rates would plausibly be getting close to neutral rate territory. This meant that the point was approaching where monetary policy might no longer be characterised as restrictive.

    In this context, the remark was made that the public debate about the natural or neutral rate among market analysts and observers was becoming more intense, with markets trying to gauge the Governing Council’s assessment of it as a proxy for the terminal rate in the current rate cycle. This debate was seen as misleading, however. The considerable uncertainty as to the level of the natural or neutral interest rate was recalled. While the natural rate could in theory be a longer-term reference point for assessing the monetary policy stance, it was an unobservable variable. Its practical usefulness in steering policy on a meeting-by-meeting basis was questionable, as estimates were subject to significant model and parameter uncertainty, so confidence bands were too large to give any clear guidance. Moreover, the natural rate was a steady state concept, which was hardly applicable in a rapidly changing environment – as at present – with continuous new shocks.

    Moreover, it was mentioned that a box describing the latest Eurosystem staff estimates of the natural rate would be published in the Economic Bulletin and pre-released on 7 February 2025. The box would emphasise the wide range of point estimates, the properties of the underlying models and the considerable statistical uncertainty surrounding each single point estimate. The view was expressed that there was no alternative to the Governing Council identifying, meeting by meeting, an appropriate policy rate path which was consistent with reaching the target over the medium term. Such an appropriate path could only be identified in real time, taking into account a sufficiently broad set of information.

    Turning to communication aspects, it was widely stressed that maintaining a data-dependent approach with full optionality at every meeting was prudent and continued to be warranted. The present environment of elevated uncertainty further strengthened the case for taking decisions meeting by meeting, with no room for forward guidance. The meeting-by-meeting approach, guided by the three-criteria framework, was serving the Governing Council well and members were comfortable with the way markets were interpreting the ECB’s reaction function. It was also remarked that data-dependence did not imply being backward-looking in calibrating policy. Monetary policy was, by definition, forward-looking, as it affected inflation in the future and the primary objective was defined over the medium term. Data took many forms, and all relevant information had to be considered in a timely manner.

    Taking into account the foregoing discussion among the members, upon a proposal by the President, the Governing Council took the monetary policy decisions as set out in the monetary policy press release. The members of the Governing Council subsequently finalised the monetary policy statement, which the President and the Vice-President would, as usual, deliver at the press conference following the Governing Council meeting.

    Monetary policy statement

    Monetary policy statement for the press conference of 30 January 2025

    Press release

    Monetary policy decisions

    Meeting of the ECB’s Governing Council, 29-30 January 2025

    Members

    • Ms Lagarde, President
    • Mr de Guindos, Vice-President
    • Mr Centeno
    • Mr Cipollone
    • Mr Demarco, temporarily replacing Mr Scicluna
    • Mr Dolenc, Deputy Governor of Banka Slovenije
    • Mr Elderson
    • Mr Escrivá*
    • Mr Holzmann
    • Mr Kālis, Acting Governor of Latvijas Banka
    • Mr Kažimír
    • Mr Knot
    • Mr Lane
    • Mr Makhlouf*
    • Mr Müller
    • Mr Nagel
    • Mr Panetta
    • Mr Patsalides*
    • Mr Rehn
    • Mr Reinesch
    • Ms Schnabel
    • Mr Šimkus
    • Mr Stournaras*
    • Mr Villeroy de Galhau
    • Mr Vujčić*
    • Mr Wunsch

    * Members not holding a voting right in January 2025 under Article 10.2 of the ESCB Statute.

    Other attendees

    • Mr Dombrovskis, Commissioner**
    • Ms Senkovic, Secretary, Director General Secretariat
    • Mr Rostagno, Secretary for monetary policy, Director General Monetary Policy
    • Mr Winkler, Deputy Secretary for monetary policy, Senior Adviser, DG Monetary Policy

    ** In accordance with Article 284 of the Treaty on the Functioning of the European Union.

    Accompanying persons

    • Mr Arpa
    • Ms Bénassy-Quéré
    • Mr Debrun
    • Mr Gavilán
    • Mr Gilbert
    • Mr Kaasik
    • Mr Koukoularides
    • Mr Lünnemann
    • Mr Madouros
    • Mr Martin
    • Mr Nicoletti Altimari
    • Mr Novo
    • Mr Rutkaste
    • Ms Schembri
    • Mr Šiaudinis
    • Mr Šošić
    • Mr Tavlas
    • Mr Ulbrich
    • Mr Välimäki
    • Ms Žumer Šujica

    Other ECB staff

    • Mr Proissl, Director General Communications
    • Mr Straub, Counsellor to the President
    • Ms Rahmouni-Rousseau, Director General Market Operations
    • Mr Arce, Director General Economics
    • Mr Sousa, Deputy Director General Economics

    Release of the next monetary policy account foreseen on 3 April 2025.

    MIL OSI Europe News

  • MIL-OSI Asia-Pac: A high-level European Union delegation, led by Ms Ekaterina Zaharieva, currently on India visit, today called on Union Minister for Science and Technology, Dr. Jitendra Singh and discussed primarily the StartUp and innovation collaborations

    Source: Government of India

    A high-level European Union delegation, led by Ms Ekaterina Zaharieva, currently on India visit, today called on Union Minister for Science and Technology, Dr. Jitendra Singh and discussed primarily the StartUp and innovation collaborations

    The meeting between Ekaterina, who is the European Union Commissioner for Startups, Research and Innovation and the Indian Minister marks a significant milestone in India-EU cooperation in the field of science and technology

    Recalls the long-standing and growing cooperation between India and the European Union (EU) in the field of science and technology

    “Prime Minister Narendra Modi Instrumental in Making India a hub of hub of cutting-edge research, fostering innovation, and driving transformative initiatives across various scientific domains” says Dr. Singh

    Highlights AI, Quantum Mission, healthcare, Ocean Polar along with other areas with potential of India -EU collaboration

    Posted On: 27 FEB 2025 8:27PM by PIB Delhi

    A high-level European Union delegation, led by Ms Ekaterina Zaharieva, currently on India visit, today called on Union Minister of State (Independent Charge) for Science and Technology, Dr. Jitendra Singh and discussed primarily the StartUp and innovation collaborations.

    The meeting between Ekaterina, who is the European Union Commissioner for Startups, Research and Innovation and the Indian Minister marks a significant milestone in India-EU cooperation in the field of science and technology.

    The Science and Technology Minister emphasized the longstanding partnership between India and the European Union, which dates back to the signing of the India-EU Science and Technology Agreement in 2001, renewed in 2015 and 2020, and set to be renewed once again for the period 2025-2030.

    Dr. Jitendra Singh credited Prime Minister Narendra Modi for his visionary leadership and unwavering support, which has played a pivotal role in India’s remarkable leap in science and technology. He noted that PM Modi has been instrumental in steering the country towards becoming a hub of cutting-edge research, fostering innovation, and driving transformative initiatives across various scientific domains.

    During the discussions, Dr. Jitendra Singh highlighted several key areas where India and the EU can collaborate further to drive innovation and sustainable development.

    These areas include:

    Water Resource Management

    Clean Energy & Smart Grids

    Artificial Intelligence (AI), Data & Robotics

    Healthcare (including Vaccine Development and Pandemic Preparedness)

    Climate Change & Polar Research

    The Minister stressed that collaboration in these areas would harness the strengths of both India and Europe, with an emphasis on increasing synergy and sharing knowledge and resources.

    Dr. Singh underscored India’s commitment to advancing joint research initiatives with the EU, particularly during the period from 2020 to 2024. He referred to ongoing projects such as:

    Department of Science and Technology (DST): Projects on Water, Energy, AI, Data, and Robotics

    Department of Biotechnology (DBT): Collaborative work on Water Resources and Vaccine Development

    Ministry of Earth Sciences (MoES): Joint research on Climate Change and Polar Research

    The Minister emphasized India’s substantial contribution to these projects, amounting to €20.92 million. He also named several noteworthy achievements and projects, including:

    Geospatial Mapping of Point/Non-Point Pollution Sources (SPRING)

    PAVITRA GANGA: Demonstration of novel wastewater treatment technologies at Kanpur and Barapullah, New Delhi

    ENDFLU: Development of an improved influenza vaccine (Myn002) for better protection against drifted influenza strains

    BRIC-THSTI: Development of domestic influenza vaccine testing capacity through the ENDFLU and INCENTIVE projects

    PRESCRIP-TEC: HPV awareness and screening initiatives

    RUTI®: Phase 1 trials of Anti-TB vaccine

    The Minister of Earth Sciences, Dr. Singh, further emphasized the importance of international collaboration in addressing oceanic and climatic challenges. Key areas of research include:Ocean warming, deoxygenation, and acidification;Polar climate studies;Ocean forecasting.

    Dr. Jitendra Singh stressed the need for global cooperation to address these threats and ensure the health of the planet’s ecosystems.

    Looking ahead, Dr. Singh outlined several promising areas for future India-EU collaboration:

    Quantum Research: India’s emerging Quantum R&D capabilities combined with the EU’s advanced quantum hardware can lead to breakthroughs in secure communication and computing.

    Bioeconomy: India’s first-of-its-kind Bioeconomy (BioE3) policy, along with the EU’s expertise, can foster growth in the sector.

    Green Hydrogen: India’s scaling renewable hydrogen projects, paired with the EU’s leadership in electrolysis technology, can drive transformational change in energy.

    Battery Technology & Blue Economy: Exploring innovations in energy storage and sustainable use of ocean resources.

    High-Performance Computing: Enhancing computational capabilities for scientific and industrial applications.

    Dr. Singh also highlighted India’s commitment to tackling climate change through clean energy collaboration, particularly in offshore wind and solar projects. This, he said, would help meet the ambitious climate targets set by both India and the EU.

    The S&T Minister pointed out that India’s National AI Mission, backed by substantial funding, will be a key area for collaboration between India and the EU. He emphasized the potential for both regions to lead in AI safety and security, ensuring the development of AI in a sustainable, equitable, and inclusive manner.

    In the health sector, Dr. Singh identified several key areas where India and the EU can collaborate:Infectious and Non-Infectious Diseases; Novel Therapeutics, Biologicals, and Early Diagnostics; Drug Repurposing; AI in Healthcare Antimicrobial Resistance (AMR); One Health Approach.

    He stressed that the partnership between India and Europe could extend to these critical health challenges, which have global implications.

    From the Directorate-General for Research and Innovation, Mr. Marc Lemaître, Director-General; Ms. Nienke Buisman, Head of Unit, Innovation, Prosperity, and International Cooperation; and from the Cabinet of the Commissioner, Ms. Sophie Alexandrova, Deputy Head of Cabinet, along with Mr. Ivan Dimov, Member of Cabinet; Mr. Pierrick Fillon-Ashida, First Counsellor & Head of the Research & Innovation Section; Dr. Vivek Dham, Policy Officer, Research & Innovation Section, EU Delegation to India, were part of the delegation.

    Dr. Jitendra Singh concluded the discussions by reiterating India’s deep commitment to strengthening its partnership with the European Union in science and technology. He expressed confidence that the shared vision for collaboration in key sectors will create a pathway to solving global challenges and advancing mutual interests.

    ********

    NKR/PSM

    (Release ID: 2106749) Visitor Counter : 41

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  • MIL-OSI Asia-Pac: National Science Day to be celebrated with theme ‘Empowering Indian Youth for Global Leadership in Science & Innovation for Viksit Bharat’

    Source: Government of India

    Posted On: 27 FEB 2025 8:26PM by PIB Delhi

    Union Minister of State (Independent Charge) Science & Technology; Minister of State (Independent Charge) Earth Sciences; MoS PMO, Personnel, Public Grievances, Pensions, Atomic Energy and Space, Dr Jitendra Singh will grace the National Science Day (NSD) 2025 celebration at Vigyan Bhawan on February 28, 2025.

    The theme of the programme this year is “Empowering Indian Youth for Global Leadership in Science & Innovation for Viksit Bharat”. The theme has been inspired by the emphasis of Hon’ble Prime Minister Shri Narendra Modi on the power of the youth to innovate and bring about transformations and his dream of Viksit Bharat through global leadership in S&T.

    Two National Science Day lectures will be also delivered on the theme by Shri Shashi S. Vempati, Co-Founder AI4India & Former CEO Prasar Bharati and Prof. Sanjay Behari, Director, Sree Chitra Tirunal Institute for Medical Sciences and Technology, Kerala.

    NSD is celebrated every year on February 28 to commemorate the discovery of the ‘Raman Effect.’ The Government of India designated February 28 as National Science Day (NSD) in 1986. On this day, Sir C.V. Raman announced the discovery of the ‘Raman Effect’ for which he was awarded the Nobel Prize in 1930. On this occasion, theme-based science communication activities are carried out all over the country.

    Its celebrations are targeted to increase public appreciation of the scientific issues involved, bring scientific awareness in the country and to encourage curiosity and understanding about science and entice young people to pursue science. Many institutions organize open house sessions for their laboratories and appraise students about career opportunities available in the respective research laboratories/institutions.

    National Council for Science & Technology Communication (NCSTC), Department of Science and Technology (DST) acts as a nodal agency to support, catalyse and coordinate the celebration of the National Science Day throughout the country in scientific institutions, research laboratories and autonomous scientific institutions associated with the Department of Science and Technology. NCSTC also supports various programmes like lectures, quizzes, open house sessions across the country through State S&T Councils & Departments.

    ****

    NKR/PSM

    (Release ID: 2106748) Visitor Counter : 51

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  • MIL-OSI Asia-Pac: Chief Minister of Maharashtra and Union Minister of State for Power and New & Renewable Energy addressed the 2nd meeting of Group of Ministers on viability of distribution utilities.

    Source: Government of India (2)

    Chief Minister of Maharashtra and Union Minister of State for Power and New & Renewable Energy addressed the 2nd meeting of Group of Ministers on viability of distribution utilities.

    Renewable Energy as panacea for increasing supply and reducing cost of power

    Inflation-indexed and cost-reflective power tariffs need of the hour.

    Need for Regulatory Reforms for Power Distribution.

    Posted On: 27 FEB 2025 7:57PM by PIB Delhi

    The 2nd meeting of Group of Ministers (GoM), constituted for addressing issues related to viability of electricity distribution utilities, was held in Mumbai today in the presence of Shri Devendra Fadnavis, Hon’ble Chief Minister of Maharashtra, also holding the portfolio of Energy Ministry in the State, and Shri Shripad Yesso Naik, Hon’ble Union Minister of State for Power and New & Renewable Energy as Chairman of the GoM.

    Thiru V Senthil Balaji, Hon’ble Minister of Electricity, Tamil Nadu, Dr. Somendra Tomar, Hon’ble Minister of State for Energy, Uttar Pradesh, and Smt. Meghana Sakore Bordikar, Hon’ble Minister of State for Energy, Maharashtra attended the meeting. Shri Gottipati Ravikumar, Hon’ble Minister of Energy, Andhra Pradesh and Shri Heeralal Nagar, Hon’ble Minister of State for Energy, Rajasthan attended the meeting through video-conference. The meeting was also attended by officials from Central Government, State Governments and Power Utilities of member States, Power Finance Corporation (PFC) Ltd and REC Ltd.

    In his opening remarks, Union Minister of State welcomed Energy Ministers from the member States and thanked Chief Minister, Maharashtra, for hosting the meeting. He highlighted the discussions held in the first meeting of the GoM and the collective efforts required from the members for improvement in power Distribution sector. He highlighted about 4 key parameters and their relevance to improving viability of distribution utilities viz. Aggregate Technical and Commercial (AT&C) Loss, Gap between Average Cost of Supply and Average Revenue Realised (ACS-ARR Gap), Accumulated Losses and Outstanding debts.

    Union Minister expressed that every 1% increase of AT&C loss results in monetary losses for utilities in upwards of Rs. 10,000 Cr. He stressed upon the need for leveraging renewable energy (RE) for reducing cost of power in line with the initiatives taken by Maharashtra and Rajasthan. He highlighted about various short, medium and long term strategies to supplement the efforts towards viability of power distribution sector. He mentioned about the use of advanced technologies such as Artificial Intelligence for demand forecasting and power purchase optimisation, establishing mechanism for timely payment of Government dues, sharing best practices amongst DISCOMs, development of renewable energy, energy storage and expediting works under Revamped Distribution Sector Scheme (RDSS), as the key interventions.

    In his address Chief Minister of Maharashtra thanked Union Minister of State for having the 2nd meeting of the Group of Ministers in Mumbai. He commended that the measures taken by the Government of India will have far reaching impact on making country’s distribution sector stronger and healthier. He highlighted about the energy distribution across different consumer categories in the State. He emphasised on the need for expeditious growth of renewable sources of energy couple with energy storage solutions so as to meet the future challenges of energy transition and growing power demand.

    He further highlighted the efforts made by the State towards RE deployment under Mukhyamantri Saur Krishi Vahini Yojana facilitating day time power supply to farmers thereby reducing cost of power and reducing subsidy burden of the State. He mentioned that the State is expeditiously working towards solarization of all the Agricultural load feeders.

    He assured for improvement in AT&C loss figures of the State in the coming years. He mentioned about progress made by the State under the RDSS. He highlighted the importance of Resource Adequacy plan, use of AI tools etc. He requested support of Government of India (GoI) for early release of Gross Budgetary Support (GBS) under RDSS, reintroduction of schemes like UDAY (Ujjwal DISCOM Assurance Yojana), lowering interest rates on loans charged by REC Ltd. and Power Finance Corporation (PFC) Ltd., and waiver or reduction in their prepayment charges. He urged for having regulatory relaxations for allowing surplus of DISCOMs towards infrastructure development and reducing debt burden before passing it on further.

    Joint Secretary (Distribution), Ministry of Power made a presentation highlighting status of key financial and operational parameters of member States.

    The contours of the Action plan identifying the ways to reduce the outstanding debts and losses of the Distribution Utilities and the means to bring them into profits, were discussed in detail.

    State of Gujarat, as a special invitee, shared the best practices adopted and their journey toward making their DISCOMs profitable.

    The member States actively participated in the meeting and presented the overview of State DISCOMs. They gave valuable suggestions for improving the financial condition of DISCOMs. State of Maharashtra, Tamilnadu, Uttar Pradesh, Andhra Pradesh, and Rajasthan, made presentations covering status, reforms undertaken, best practices and way forward for the GoM.

    PRAYAS group made a presentation highlighting reforms that may be undertaken for having a financially viable distribution sector.

    The Group of Ministers reiterated its commitment and expressed resolve to take necessary measures for improving the financial viability of DISCOMs.

    In his closing remarks, Hon’ble Union Minister of State mentioned that the inputs/ suggestions provided by the States would be helpful in shaping the policies and further course of action and urged the member States to work upon the action points that have emerged during the meeting.

    It was also unanimously decided to have 3rd meeting of GoM in Uttar Pradesh in the month of March.

    *****

    JN / SK 

    (Release ID: 2106731) Visitor Counter : 55

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  • MIL-OSI Europe: Written question – Effective gastric cancer screening in the EU – E-000711/2025

    Source: European Parliament

    Question for written answer  E-000711/2025
    to the Commission
    Rule 144
    Tomislav Sokol (PPE)

    Gastric cancer is the sixth most diagnosed cancer in Europe, with 136 000 new cases diagnosed annually and 52 085 deaths per year in the EU. The disease disproportionately affects eastern and central Europe, which has the second-highest incidence rates worldwide behind eastern Asia. The 2022 Council Recommendation[1] calls for the establishment of gastric cancer screening programmes in high-prevalence countries. However, no gastric cancer screening programmes have been organised in the EU to date.

    Given the foregoing:

    • 1.How does the Commission plan to encourage and support Member States in implementing the 2022 Council Recommendation?
    • 2.Will the Commission support the Member States concerned in developing national screening programmes for gastric cancer?
    • 3.What steps is the Commission taking to promote the development and adoption of non-invasive screening methods, such as biomarker-based blood tests, to improve patient compliance and accessibility of gastric cancer screening?

    Submitted: 17.2.2025

    • [1] Council Recommendation of 9 December 2022 on strengthening prevention through early detection: A new EU approach on cancer screening replacing Council Recommendation 2003/878/EC, OJ C 473, 13.12.2022, p. 1.
    Last updated: 27 February 2025

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