Category: Energy

  • MIL-OSI New Zealand: Rules to be eased to drive investment in electricity

    Source: New Zealand Government

    Restrictions on electricity lines companies investing in generation will be eased to help strengthen the energy network, Energy Minister Simon Watts and Associate Energy Minister Shane Jones say.

    “This action, which is part of the coalition agreement between New Zealand First and National, will give distribution businesses the confidence they need to invest in generation, helping to increase regional resilience and the national energy supply,” Mr Jones says.

    Distribution businesses are currently prohibited from owning more than 250 MW of generation connected to Transpower’s national grid, and/or more than 50 MW of generation connected to their own networks unless they operate that generation in a separate company or seek an exemption from the Electricity Authority. 

    “The current rules place undue costs on distributors, given that other regulations cover similar ground. The exemption process can also impose costs, as well as cause delay and uncertainty, which we are striving to avoid,” Mr Jones says.

    Safeguards in both the Electricity Authority’s Code and the Commerce Act that provide protections for competition will apply to distribution businesses’ investment in generation.

    Mr Watts says the change will further drive the investment needed in generation while continuing to preserve competition.

    “It is very difficult to grow the economy when energy security is at risk. This change is among a number of measures the Government is taking to ensure businesses and ordinary Kiwis have access to a reliable and secure energy supply.”

    The change will be included in the Energy and Electricity Security Bill which is expected to be introduced in the first half of this year.

    MIL OSI New Zealand News

  • MIL-OSI Australia: Powering communities: Round 2 of ARENA’s community batteries program launched

    Source: Australian Renewable Energy Agency

    Overview

    • Category

      News

    • Date

      26 February 2025

    • Classification

      Battery storage

    The Australian Renewable Energy Agency (ARENA) has today announced $46.3 million in funding for Round 2 of the Community Batteries Funding Program.

    Building on the success of Round 1, this program aims to deploy community batteries across Australia to lower energy bills, cut emissions and reduce pressure on the electricity grid.

    ARENA is now seeking applications to deploy community batteries. Projects should improve the economics of community battery projects, build industry capacity, support the integration of distributed energy resources into Australian energy markets, or demonstrate benefits of community batteries.

    To be eligible for ARENA funding, each community battery must be between 50 kW and 5 MW in size and connected to the distribution network.

    Community batteries provide energy storage in the distribution network that can store excess solar energy for later use, enabling higher penetrations of rooftop solar, putting downward pressure on household costs and easing pressure on local electricity grids.

    ARENA CEO Darren Miller said batteries are a critical part of the transition to net zero as the grid transitions to energy generated from renewable sources.

    “Part of increasing our dependency on renewably sourced energy is the need to increase our firming technology to make sure the energy grid is secure and reliable. We can achieve this by storing energy in batteries when renewable energy is plentiful and use this stored energy later in the day and overnight when people most need it,” said Mr Miller.

    “Over recent years, a concerted effort has been made in deploying batteries to support the grid and transition to clean energy. Round 2 will build on the insights, expertise and knowledge developed in Round 1, resulting in further optimisation of distributed energy resources in the electricity grid”.

    As part of the 2022-23 Federal Budget, the Australian Government allocated $200 million for the Household Solar budget measure to deploy 400 community batteries across Australia.

    In total, ARENA was allocated $171 million of this funding to deliver at least 342 community batteries across rounds 1 and 2.

    More information about this program, including the application process, can be found at ARENA’s funding page. Funding applications can be submitted from 17 March 2025 to 30 April 2025.

    ARENA media contact:

    media@arena.gov.au

    Download this media release (PDF 143KB)

    MIL OSI News

  • MIL-OSI Global: The UK must make big changes to its diets, farming and land use to hit net zero – official climate advisers

    Source: The Conversation – UK – By Neil Ward, Professor of Rural and Regional Development at the Tyndall Centre for Climate Change Research, University of East Anglia

    William Edge / shutterstock

    If the UK is to achieve net zero emissions by 2050, over one-third of its sheep and cows will have to go, with their fields being replaced by huge new areas of woodland. That’s one conclusion of the latest report by the the Climate Change Committee (CCC), the UK government’s independent advisor on climate change.

    The CCC is tasked with outlining how much greenhouse gas the UK can emit if it is to achieve its climate targets – its “carbon budget”. The committee also recommends how the country might reduce its emissions to get within that budget. It sets future budgets every five years or so. This latest report, the seventh carbon budget, looks at emissions in the period 2038 to 2043. It updates the sixth carbon budget produced in 2020.

    The UK has almost halved its greenhouse gas emissions since 1990, but that was the easy half. Most dirty industries are long gone, for instance, and coal power plants have been replaced with gas and renewable energy.

    Next, the country will be grappling with the most challenging sectors including the focus of my academic research: agriculture and land use. This challenge will be worsened by the impacts of climate change and geopolitical uncertainties that raise doubts about the UK’s food security.

    Currently, agriculture makes up about 11% of UK emissions, but this proportion will rise considerably over the next 15 years as other sectors decarbonise further. Cattle and sheep contribute most of these emissions, and the latest carbon budget suggests their numbers will have to be reduced by 22% by 2035 and by over 38% by 2050.

    This is principally to release land to plant tens of thousands of hectares of new woodland each year (60,000 hectares a year by 2040) and to grow energy crops (38,000 hectares a year by 2040). It will also mean fewer emissions from the animals themselves and from growing animal feed.

    The UK needs a lot more of this.
    Callums Trees / shutterstock

    Less meat and dairy

    The latest carbon budget suggests that dietary change is key to this anticipated change in farming and land use. While British people won’t need to give up meat entirely, they will need to reduce consumption of meat and dairy products by around 35% by 2050 compared to 2019 levels.

    Meat and dairy consumption are already falling, however, and the trend has accelerated since 2020. To meet the budget, the decline would need to continue but more rapidly than the long-term trend.

    The CCC is in the business of advising on what government should do to address climate change, not in the business of telling people what to eat. It hopes that food labels with additional information about emissions will help people make better choices for themselves.

    Emphasising non-meat options and altering the layout of supermarkets may also help change the “choice environment” and so change consumption practices. Nevertheless, before long, the UK and devolved governments will have to grasp the nettle of diet change, land use and livestock. There have already been successful legal challenges for having inadequate plans in this area.

    It helps that diets good for the planet are also good for people’s health. In October 2024, the House of Lords food, diet and obesity committee estimated diet-related ill health and obesity cost £98 billion a year. This is a significant drag on productivity and places acute pressures on the NHS.

    Plant-based foods are better for food security

    Energy security is currently prompting much thought and action, but food security has not. Dietary change can also help improve the UK’s food security, however, since meat and dairy take up more land per calorie than healthier alternatives. A large-scale shift in diet and land use could render the UK more resilient to future wars, pandemics or anything else that causes shocks to food prices and supplies.

    For farmers and landowners there has been increasing interest in greener approaches to production, sometimes called regenerative farming. Some within, or clustered around, farming will protest about the scale of reduction in animal numbers implied by net zero.

    Faced with the basic maths, a marked reduction looks unavoidable. The sooner the conversation can shift from whether change is needed to how it might best be fairly and equitably pursued, the better.

    This carbon budget brings positive opportunities for nature restoration, diversifying rural economies and improving the appearance and ecology of the countryside. But for net emissions to come down enough, the amount of wooded land will need to increase from 13% to 19% by 2050 – that’s over a million extra hectares, or roughly equivalent to Cornwall, Devon and Dorset combined.

    These are very stretching targets, and tree planting over the past few years has fallen far short of the rates required. Because afforestation is such an important factor in the carbon budget, if the UK fails to meet its targets, the dietary changes may need to be even greater.

    Heightened international instability threatening UK food security could mean the same. Indeed, some food, health and environmental organisations will point to the seventh carbon budget and say the CCC has not gone far enough.


    Don’t have time to read about climate change as much as you’d like?

    Get a weekly roundup in your inbox instead. Every Wednesday, The Conversation’s environment editor writes Imagine, a short email that goes a little deeper into just one climate issue. Join the 40,000+ readers who’ve subscribed so far.


    Neil Ward receives funding from UKRI in his role as Co-lead of the AFN (AgriFood4NetZero) Network+.. He is a member of the Labour Party and the National Trust.

    ref. The UK must make big changes to its diets, farming and land use to hit net zero – official climate advisers – https://theconversation.com/the-uk-must-make-big-changes-to-its-diets-farming-and-land-use-to-hit-net-zero-official-climate-advisers-250158

    MIL OSI – Global Reports

  • MIL-OSI United Kingdom: expert reaction to the Climate Change Committee’s Seventh Carbon Budget

    Source: United Kingdom – Executive Government & Departments

    Scientists comment on the Seventh Carbon Budget, published by the Climate Change Committee. 

    Prof John Barrett, Professor in Energy and Climate Policy and Director of the Climate Evidence Unit at the University of Leeds, said:

    “This is a very welcome report with a robust analysis that lets the Government, industry and citizens know that the pathway to net zero is possible and very much needed. However, it does place enormous responsibility on some key technologies and their rapid roll out to achieve these goals. As the UK Government digests the findings, we would suggest greater consideration of the “social” transformation that examines how we travel and what we buy.”

    “While the report acknowledges some upfront costs, it confirms that acting now will reduce expenses in the long run, with cost savings emerging by the late 2030s and beyond.”

    “The key takeaway from today’s report is clear: the transition to net zero is not only possible but highly beneficial. Independent academic analyses consistently supports this conclusion, showing that it will strengthen the economy, deliver widespread co-benefits, and position the UK as a leader in global climate action.”

     

    Dr Sean Beevers, Reader in Atmospheric Modelling, School of Public Health, Imperial College London, said:

    “A National Institute for Health and Care Research project examined the effects of net zero policies on air quality, active travel, health, and associated economic benefits in the UK.

    “Our cost benefit analysis showed that net zero transport and building policies deliver substantial co-benefits, including improved indoor and outdoor air quality, better health, increase active travel, lessening inequalities and with long-term economic gains. We estimated an overall monetised air quality and active travel benefit of £46.4 billion by 2060 and £153 billion by 2154.

     “Net zero policy analyses should include benefits from the air pollution reductions and physical activity increases. These benefits apply to current and future generations and failure to act will lead to worse health outcomes and higher costs for attaining net zero.”

    Dr Edward Gryspeerdt, Research Fellow at the Department of Physics, Imperial College London, said:

    “The CCC’s advice highlights that aviation will become the highest emitting sector in the UK by 2040. Clean alternatives, such as low-carbon fuel and technology for low emission flights are currently limited and a range of measures will be needed to meet net-zero – there is no silver bullet.

    “The government has described ‘sustainable aviation fuels’ as a ‘game changer.’ However, to have a significant impact on the climate impact of flying, they will need to be produced at a huge scale. It is not yet clear how this will be achieved. To reach net zero, the CCC also note that a switch from flying to other modes of transport will be required, especially for flights with an easy rail alternative. 

    “These measures alone won’t solve the problem. The CCC’s report highlights that a significant amount of carbon capture will be needed, highlighting the simple fact that the technological solutions to eliminate the climate impact of flying don’t yet exist. Any expansion of the UK’s aviation infrastructure will have to be coupled with improved sustainable transport options.”

     

    Dr Caterina Brandmayr, Director of Policy and Translation at the Grantham Institute – Climate Change and the Environment, Imperial College London, said:

    “Today’s advice marks an important milestone in charting the UK’s path to net zero. Public opinion surveys continue to show that climate change remains a key issue of concern for a large majority of people in the UK.

     “To put us firmly on track to deliver the deep emission cuts needed from 2038 to 2042, the UK government needs to strengthen its action in the near term, giving confidence to businesses and households to invest in clean alternatives in sectors like housing, transport and energy. 

    “There is strong public support for the benefits that emission reduction interventions can bring, such as warmer homes, energy security and cleaner air. 

    “Effectively communicating these benefits, while ensuring fairness and choice in policy design, will be key to sustaining public support for the transition and driving change in harder to decarbonise sectors, such as aviation and land use.”

    Dr Friederike Otto, Senior Lecturer at the Centre for Environmental Policy and co-lead of World Weather Attribution, Imperial College London, said

    “People shouldn’t forget why we need these targets – we’re already feeling the pain at 1.3°C of warming and things will keep getting worse until emissions are reduced to net zero. 

    “Here in the UK, we’ll experience even wetter winters that could wipe out crops, threaten our food security and turn sports pitches into miserable bogs. In summer, more frequent heatwaves will contribute to thousands of premature deaths, could put additional strain on the NHS, and reduce economic productivity. Overseas, extreme weather could disrupt supply chains we depend on and could contribute to worsening political instability and conflict. 

    “Arguments that climate action is too costly are dangerous, short-sighted and disproportionately harm poorer people. If governments don’t cut emissions, both now and in the future, our children will live in an increasingly hostile climate and even more inequal society. 

    “The UK needs to push ahead and lead the way in emission reductions for a safer, healthier future.”

    Prof Lorraine Whitmarsh, Director at the Centre for Climate Change and Social Transformations (CAST) at the University of Bath, said:

    “The government’s climate advisors make clear that tackling climate change requires significant action from all sections of society in the coming years. A third of emission reductions will come from household behaviour change alone. Low-carbon choices include switching to electric vehicles and heat pumps, eating more plant-based foods, and shifting to cleaner forms of transport. Many of these changes offer wider benefits, like improved health and lower bills. The report also highlights the need for government to reduce the barriers for the public to make these changes and to engage the public more actively in the net zero transition. The citizens panel that fed into these recommendations highlight that measures need to be fair and reduce the cost of low-carbon options.”

    Dr Christina Demski, Deputy Director at the Centre for Climate Change and Social Transformations (CAST) at the University of Bath, said:

    “The latest CCC progress report makes it clear that decisive action is needed now to ensure we meet the net zero target, and that action to reduce emissions also has other benefits like economic security, better health and reducing fuel poverty. While the UK is on track to reduce emissions substantially from energy supply, the report clearly shows that action is also needed in sectors like transport, buildings and agriculture, and that this requires widespread uptake of essential low-carbon technologies like EVs and heat pumps.

    “We have long called for a comprehensive engagement strategy, so it is great to see this included as one of the key recommendations, especially the recommendation to go beyond one-way communication strategies.”

    Dr Sam Hampton, Research Fellow at the Centre for Climate Change and Social Transformations (CAST) at the University of Bath, said:

    “The Climate Change Committee’s 7th Carbon Budget provides a comprehensive account of the changes required across UK society to address the increasingly alarming impacts of climate change. As we have largely exhausted the low-hanging fruit of decarbonising our electricity supply, the focus in the 2030s and 2040s must shift towards demand-side changes. This includes changes in how we eat and travel, as well as the technologies we adopt. The report highlights key solutions including the adoption of electric vehicles and heat pumps, as well as the need for innovation to rid fossil fuels from industry. Another important takeaway is that Sustainable Aviation Fuel (SAF) is not a viable solution to decarbonising air travel. This comes just weeks after government expressed its support for airport expansion, and highlights the need for more radical solutions to limit flying, especially amongst the rich.”

     

     

    The Climate Change Committee’s Seventh Carbon Budget was published at 00:01 UK Time Wednesday 26 February 2025. 

    Declared interests

    Prof John Barrett: Deputy Director for Policy, Priestly Centre for Climate Futures, University of Leeds, Theme Leader for the UKRI Energy Research Demand Centre

    For all other experts, no reply to our request for DOIs was received.

    MIL OSI United Kingdom

  • MIL-OSI Australia: ARENA invests in cleaner, greener Australian skies

    Source: Australian Renewable Energy Agency

    The Australian Renewable Energy Agency (ARENA) is today supporting cleaner Australian skies, with up to $10.4 million in funding for two projects from its Sustainable Aviation Fuels (SAF) Funding Initiative.

    ARENA is providing $8 million in funding to Licella and $2.4 million to Viva Energy for separate studies to develop renewable fuel alternatives for Australia’s airline industry.

    ARENA CEO Darren Miller said these projects represent an important step towards developing a pipeline of projects that could support the reduction of aviation sector emissions.

    “Aviation is a challenging industry from an emissions reduction perspective with domestic flights currently accounting for approximately 2 per cent of Australia’s greenhouse gas emissions,” Mr Miller said.

    “With Australians being among the most prolific flyers in the world, decarbonising this high emissions industry will be vital for us to achieve our net zero targets.”

    “These two projects are an important step towards developing opportunities to cut emissions from Australian skies and ARENA will be working to ensure the lessons from these projects help inform the broader development of a sustainable aviation fuels industry in Australia.”

    The two projects include:

    • $8 million to Australian technology and project developer Licella for the $26.1 million ‘Project Swift – SAF from Sugarcane Residues Feasibility Study’ to complete Feasibility and Front-End Engineering Design (FEED) studies assessing the viability of establishing a biorefinery facility in Bundaberg, Queensland utilising Licella’s patented Catalytic Hydrothermal Reactor (Cat-HTR™) hydrothermal liquefaction technology to convert sugar mill residues to renewable fuels. The proposed facility would be capable of producing approximately 60 ML per annum of low carbon liquid fuels (LCLFs), of which around 40 ML per annum will be SAF.
    • $2.4 million to Viva Energy for the $4.9 million ‘SAF infrastructure Solutions for the Future project’ to recondition an existing tank at its Pinkenba Terminal to enable blended SAF supply into Brisbane Airport for commercial use. Viva will also work with industry partners to develop a book and claim system so that customers can recognise the carbon reduction benefits of the SAF supplied.The Project will conclude with Viva Energy supplying SAF into the Brisbane Joint User Hydrant Installation and demonstrate the storage and use of SAF within the existing airport. Following the project, the system will be able to supply volumes of SAF to meet customer demand.

    Viva Energy Chief Strategy Officer Lachlan Pfeiffer said the funding from ARENA is a crucial milestone in the company’s journey to supply sustainable fuel to Australia’s aviation industry.

    “By enhancing our SAF infrastructure, we are not only supporting the aviation industry’s transition to lower carbon emissions but also positioning Viva Energy as a leader in renewable energy solutions,” he said.

    “Viva Energy is well placed to import and supply SAF. Viva Energy is a trusted partner to many aviation customers and our strength lies in deep relationships and a nationwide supply chain backed by the international capability of Vitol.”

    Licella CEO Alan Nicholl said that ARENA’s funding will support the roll out in Australia of its commercial-ready Cat-HTR™ platform through the development of a SAF-focused biorefinery targeting agricultural residues in regional Queensland.

    “We are delighted to receive ARENA’s support as we move forward with the feasibility studies for our Queensland project”, Mr Nicholl said.

    Licella Executive Chairman Dr Len Humphreys highlighted the opportunity to scale this new SAF pathway.

    “Through our global partnership with Shell, we are advancing an integrated biomass-to-advanced biofuels commercial solution, one which is targeting high volumes of low-cost, low-carbon SAF”.

    ARENA has announced total funding of $33.5 million across five projects under the SAF Funding Initiative launched in 2023 to support the development of domestic SAF production to support aviation decarbonisation, with more investments to be announced beyond the previously allocated $30 million.

    The SAF funding initiative builds on the findings of ARENA’s 2021 Bioenergy Roadmap, which identified SAF produced from biomass as one of the few opportunities to reduce emissions in the aviation sector in the short to medium term. The CSIRO SAF Roadmap identified that Australia has sufficient biomass feedstocks to supply more than half of domestic jet fuel demand, demonstrating the potential impact of supporting these early projects investigating domestic SAF production capability.

    Low Carbon Liquid Fuels has been identified as a priority sector as part of the Federal Government’s Future Made in Australia Plan. ARENA has been nominated as the delivery agency for the Future Made in Australia Innovation Fund.

     

    ARENA media contact:

    media@arena.gov.au

    Download this media release (PDF 143KB)

    MIL OSI News

  • MIL-OSI Australia: Plumbers warned to get up to speed on supervision requirements or face fines

    Source: New South Wales Premiere

    Published: 26 February 2025

    Released by: Minister for Building, Minister for Skills, TAFE and Tertiary Education


    Minister for Building Anoulack Chanthivong has welcomed Building Commission NSW warning plumbers across the state to get up to speed on their supervision requirements or face fines in an upcoming targeted compliance campaign.

    Only plumbers with a NSW Government-issued contractor licence or supervisor certificate can do plumbing work without immediate supervision* to ensure work is carried out to required standards.

    To hammer home these requirements to industry, from June this year Building Commission NSW will conduct targeted compliance activities at sites across the state.

    If workers without the right licence are found to be unsupervised, Building Commission NSW can issue fines of up to $1,500 per breach.

    In the event Building Commission NSW finds repeated instances of workers being inappropriately supervised it can also suspend or cancel licences.

    Since September 2024 Building Commission NSW has detected 17 instances of incorrectly supervised plumbing work, sparking concerns plumbers are not taking their obligations seriously.

    In a recent compliance visit to an apartment building site in Port Macquarie, Building Commission NSW found five apprentices working unsupervised, resulting in the licensed plumber being fined $1,500.

    Ahead of the compliance blitz, Building Commission NSW is rolling out a wide-ranging awareness campaign to ensure plumbers around the state know how to stick to the rules.

    The awareness campaign will include direct emails to plumbers across the state, the distribution of newsletters, and engagement with peak bodies, industry and training organisations.

    To further educate plumbers on the supervision requirements, TAFE NSW and Building Commission NSW have also launched a new Plumbing, Drainage and Gasfitting Regulation short course.

    Developed in consultation with industry and subject matter experts, the new online short course also provides regulatory knowledge and best practice skills required by plumbing professionals.

    TAFE NSW students undertaking their Certificate IV in Plumbing and Services can enroll in the course fully discounted until 1st October 2025.

    For more information on the course, please visit the Plumbing, drainage and gasfitting regulation in NSW course webpage.

    For more information on plumbing supervision requirements, please visit the Plumbing, drainage and gasfitting work webpage.

    *Building Commission NSW views ‘immediate supervision’ as the relevant licence holder:

    • Always being physically present and with clear line of sight of the work being carried out by the person they are supervising.
    • Being readily available to provide specific instructions and guidance to enable the work to be undertaken correctly by the individual performing it.
    • Directly overseeing and reviewing the work.
    • Ensuring the completed work is compliant and meets all regulatory requirements.

    Quotes to be attributed to Minister for Building Anoulack Chanthivong:

    “The Minns Labor Government aims to keep every part of the building industry in check through a strong regulatory presence, while also supporting the workforce to comply with its obligations.

    “Building Commission NSW inspections have revealed a concerning lack of awareness about plumbing supervision requirements or even some plumbers deliberately cutting corners. 

    “The point of these requirements is to make sure young apprentices work in a safe environment supported by more experienced workers who will ensure work is done to the required standards while also passing on skills to the next generation of plumbers.

    “We want to give fair warning to the plumbing industry in NSW to pull itself into line and brush up on their supervision requirements.

    “But when the inspectors’ boots hit the ground later this year, plumbers should expect the full weight of the regulator will be put behind the penalties they issue.”

    Quotes to be attributed to Minister for Skills, TAFE and Tertiary Education Steve Whan:

    “The Plumbing, Drainage and Gasfitting Regulation Microskill course is the latest in a range of courses developed in consultation with industry and subject matter experts aimed at providing the regulatory knowledge and best practice skills required by plumbing professionals to meet the state’s high standards of construction.

    “The course provides engaging, flexible, and industry-responsive learning where students can progress at their own pace and have access to the course for up to six months from the day of enrolment.

    “By offering this Microskill fully discounted to Certificate IV in Plumbing and Services students, TAFE NSW and Building Commission NSW are helping graduates build the right skills from day one.”

    Quotes to be attributed to NSW Building Commissioner James Sherrard:

    “Building Commission NSW is seeing a serious lack of awareness about plumbing supervision requirements, with inspectors consistently finding apprentices left on site unsupervised.

    “What licenced plumbers need to remember, is that even if one of their workers has finished their studies at TAFE NSW, if they don’t have the right NSW Government licence they need to be supervised.

    “These supervision requirements are in place to ensure the quality of plumbing work is maintained across NSW, protecting homeowners from expensive repairs down the track.

    “In June our specialist trade inspectors will be out in force to ensure the industry is complying with the requirements, but in the meantime, plumbers are urged to get up to speed.”

    MIL OSI News

  • MIL-OSI United Kingdom: expert reaction to study suggesting high dietary fish intake linked to slowed disability progression in Multiple sclerosis (MS)

    Source: United Kingdom – Executive Government & Departments

    A study published in the Journal of Neurology, Neurosurgery and Psychiatry looks at fish intake and slowed disability progress in Multiple Sclerosis (MS). 

    Dr Shelly Coe, Senior Lecturer in Nutrition Science, Oxford Brookes University, said:

    “It is great to see more research into MS and diet approaches for managing symptoms and disability progression, with the current research showing that higher lean and oily fish consumption is associated with a reduced risk of MS disability progression. Benefits of this study include the high sample size and that people with MS have a confirmed diagnosis and are recruited from clinics throughout Sweden.

    “Fish consumption is assessed with a 4-point scale for oily or lean fish intake, and therefore this could result in some limitations; however considering the study design this is overall a suitable method for assessing diet in this population.

    “Those with higher lean and oily fish intake overall showed an association with lower disability progression. More benefits were found in those who consistently had a higher fish consumption over time, however those who increased their fish consumption over time also had an associated reduced disability progression, although less pronounced. This therefore highlights that even if someone with MS changes their diet later in their condition to a diet richer in oily and lean fish, there is still a beneficial association with disability progression to some extent. Overall, analysis seems thorough considering all aspects of the data.”

     

    Dr Aravinthan Varatharaj, Clinical Lecturer in Neurology, University of Southampton, said:

    “This is a well-conducted study with robust findings. Sweden has an excellent registry where most people with multiple sclerosis include their data. Using this data, the researchers found that people eating more fish were relatively protected against worsening of their disability.

    “There could be lots of reasons for this. All fish contain important nutrients and amino acids which are beneficial for health. Oily fish contain essential omega-3 fatty acids which cannot be otherwise produced by the human body. UK guidelines recommend we eat at least two portions of fish per week, with at least one of oily fish. However, most people in the UK eat less than this, and only a minority regularly eat oily fish. People with multiple sclerosis already know the importance of a healthy balanced diet, and this study is another bit of evidence to say that eating more fish is good for you.

    “The study also showed that for people who didn’t each much fish and were diagnosed with multiple sclerosis, if they started eating more they still benefited. This goes to show that making a lifestyle change after diagnosis can have a positive impact.

    “However, previous studies done in the 1970s looking at fish oil supplementation did not show a strong benefit for people with multiple sclerosis. Dietary studies can be at risk of confounding by hidden factors. One thing this study didn’t look at is whether people who ate less fish were also less well-off. Fish can be expensive, so this could be a factor. We know that people with lower incomes have worse health outcomes (for multiple sclerosis and many other conditions).”

    Dr Ruth Dobson, Clinical Senior Lecturer in Neurology (Multiple Sclerosis), Queen Mary University of London (QMUL), said:

    “The Swedish EIMS study has done a lot to enhance our understanding of MS epidemiology. The question about fish consumption playing a role in MS susceptibility and/or severity is one that has been hypothesised for some time from a biological basis. Diet is of significant interest to people living with MS, and high quality studies to investigate the effect of diet are hard to do; this study provides a really useful avenue for investigation.

    “There appears to be a consistent dose-response relationship between fish consumption and MS severity, the first time this has been reliably described. Notably, the same is true for physical activity and smoking behaviour, which has been shown before.

    “I don’t think this fully answers the question about whether it is fish consumption directly that influences MS (although this is completely plausible), whether it is synergistic with other lifestyle traits (I think this is most likely), or whether it is purely acting as a surrogate for other lifestyle traits (less likely). They do adjust for some of these but residual confounding remains a concern in all studies like this. But the paper as presented is fair and does discuss this.”

    Impact of fish consumption on disability progression in multiple sclerosis’ Eva Johansson et al. was published in Journal of Neurology, Neurosurgery and Psychiatry at 23:30 hours UK time Tuesday 25 February 2025. 

    DOI: 10.1136/jnnp-2024-335200

    Declared interests

    Dr Aravinthan Varatharaj: I am involved in trials of disease-modifying treatments for progressive multiple sclerosis. I am also an investigator on the UK MS Register. I have received funding from Roche who make pharmaceuticals for MS.

    Dr Ruth Dobson: No COIs relating to this research.

    For all other experts, no response to our request for DOIs was received.

    MIL OSI United Kingdom

  • MIL-OSI USA News: Addressing the Threat to National Security from Imports of Copper

    Source: The White House

    class=”has-text-align-left”>By the authority vested in me as President by the Constitution and the laws of the United States of America, including section 232 of the Trade Expansion Act of 1962, as amended (19 U.S.C. 1862) (Trade Expansion Act), it is hereby ordered:

    Section 1.  Policy.  Copper is a critical material essential to the national security, economic strength, and industrial resilience of the United States.  Copper, scrap copper, and copper’s derivative products play a vital role in defense applications, infrastructure, and emerging technologies, including clean energy, electric vehicles, and advanced electronics.  The United States faces significant vulnerabilities in the copper supply chain, with increasing reliance on foreign sources for mined, smelted, and refined copper.

    The United States has ample copper reserves, yet our smelting and refining capacity lags significantly behind global competitors.  A single foreign producer dominates global copper smelting and refining, controlling over 50 percent of global smelting capacity and holding four of the top five largest refining facilities.  This dominance, coupled with global overcapacity and a single producer’s control of world supply chains, poses a direct threat to United States national security and economic stability.

    It is the policy of the United States to ensure a reliable, secure, and resilient domestic copper supply chain.  The United States’ increasing dependence on foreign sources of copper, particularly from a concentrated number of supplier nations, along with the risk of foreign market manipulation, necessitate action under section 232 of the Trade Expansion Act to determine whether imports of copper, scrap copper, and copper’s derivative products threaten to impair national security.

    Sec. 2.  Investigation Into the National Security Impact of Copper Imports.  (a)  The Secretary of Commerce shall initiate an investigation under section 232 of the Trade Expansion Act to determine the effects on national security of imports of copper in all forms, including but not limited to:

    (i)    raw mined copper;

    (ii)   copper concentrates;

    (iii)  refined copper;

    (iv)   copper alloys;

    (v)    scrap copper; and

    (vi)   derivative products.

    (b)  In conducting the investigation described in subsection (a) of this section, the Secretary of Commerce shall assess the factors set forth in 19 U.S.C. 1862(d), labeled “Domestic production for national defense; impact of foreign competition on economic welfare of domestic industries,” as well as other relevant factors, including:

    (i)     the current and projected demand for copper in United States defense, energy, and critical infrastructure sectors;

    (ii)    the extent to which domestic production, smelting, refining, and recycling can meet demand;

    (iii)   the role of foreign supply chains, particularly from major exporters, in meeting United States demand;

    (iv)    the concentration of United States copper imports from a small number of suppliers and the associated risks;

    (v)     the impact of foreign government subsidies, overcapacity, and predatory trade practices on United States industry competitiveness;

    (vi)    the economic impact of artificially suppressed copper prices due to dumping and state-sponsored overproduction;

    (vii)   the potential for export restrictions by foreign nations, including the ability of foreign nations to weaponize their control over refined copper supplies;

    (viii)  the feasibility of increasing domestic copper mining, smelting, and refining capacity to reduce import reliance; and

    (ix)    the impact of current trade policies on domestic copper production and whether additional measures, including tariffs or quotas, are necessary to protect national security.

    Sec. 3.  Required Actions.  (a)  The Secretary of Commerce shall consult with the Secretary of Defense, the Secretary of the Interior, the Secretary of Energy, and the heads of other relevant executive departments and agencies as determined by the Secretary of Commerce to evaluate the national security risks associated with copper import dependency.

    (b)  Within 270 days of the date of this order, the Secretary of Commerce shall submit a report to the President that includes:

    (i)    findings on whether United States dependence on copper imports threatens national security;

    (ii)   recommendations on actions to mitigate such threats, including potential tariffs, export controls, or incentives to increase domestic production; and

    (iii)  policy recommendations for strengthening the United States copper supply chain through strategic investments, permitting reforms, and enhanced recycling initiatives.

    Sec. 4.  General Provisions.  (a)  Nothing in this order shall be construed to impair or otherwise affect:

    (i)   the authority granted by law to an executive department or agency, or the head thereof; or

    (ii)  the functions of the Director of the Office of Management and Budget relating to budgetary, administrative, or legislative proposals.

    (b)  This order shall be implemented consistent with applicable law and subject to the availability of appropriations.

    (c)  This order is not intended to, and does not, create any right or benefit, substantive or procedural, enforceable at law or in equity by any party against the United States, its departments, agencies, or entities, its officers, employees, or agents, or any other person.

    THE WHITE HOUSE,

        February 25, 2025.

    MIL OSI USA News

  • MIL-OSI Economics: Media release: Boosting gas supply a priority for Australia’s economic and energy security – Australian Energy Producers

    Source: Australian Petroleum Production & Exploration Association

    Headline: Media release: Boosting gas supply a priority for Australia’s economic and energy security – Australian Energy Producers

    Australian Energy Producers today released its priorities to restore Australia’s competitiveness and ensure reliable and affordable gas for Australians ahead of the federal election. The industry’s plan for Australia’s economic and energy security comes as new polling in key Western Australian seats confirms strong support for the natural gas industry and its role in WA’s long-term energy mix.

    Australian Energy Producers Chief Executive Samantha McCulloch said the industry’s federal election platform outlines key actions for the next Australian Government to unlock the economic, energy security and emissions reduction potential of Australia’s abundant gas resources.

    “Natural gas will play an essential role in Australia’s energy mix to 2050 and beyond, but regulatory uncertainty, approval delays and policy interventions have delayed critical projects and damaged Australia’s reputation as a safe place to invest,” Ms McCulloch said.

    “Australia has abundant gas resources and yet we are facing forecast gas shortfalls on the east coast from 2027 and from 2030 in Western Australia.

    “Without new gas projects, Australian households and businesses face higher energy prices, uncertain energy supply, and increased risk of blackouts that will hit every part of the economy. Addressing these risks should be a national priority.”

    Australian Energy Producers is urging the major parties to commit to working with industry on the following priority actions:

    • Boost Australian gas supply to ease cost of living pressures
    • Restore Australia’s global competitiveness for investment
    • Deliver real emissions reductions with gas and carbon capture, utilisation and storage (CCUS)
    • Remain a reliable energy partner in our region

    “Australia and our region’s economic growth and energy security needs reliable and affordable gas supply, and this requires continued investment in new gas exploration and development,” Ms McCulloch said.

    “The Australian gas industry contributes $105 billion a year to the Australian economy and supports 215,000 jobs. Natural gas provides around 40 per cent of the energy used by Australia’s manufacturing sector, and in WA gas provides more than half the energy used in mining and minerals processing.

    “Polling confirms that Western Australians understand the importance of natural gas to the state’s economy. The next Australian Government should take note and prioritise actions to boost new gas supply, address approval delays, and ensure reliable and affordable energy for Australian households and businesses.”

    Read Australian Energy Producers’ policy platform for the 2025 Federal Election: https://energyproducers.au/2025election    

    Key findings from JWS Research polling in the electorates of Curtin, Tangney and Bullwinkel are summarised below.

    JWS Research polling results relating to the natural gas sector 

    JWS conducted online polling on 11-12 February on behalf of Australian Energy Producers, with around 830 respondents in each electorate. Key results of voters’ views on the role of natural gas in WA’s energy mix and its importance to the WA economy are summarised below. 

    Curtin

    • 73% support WA’s natural gas industry
    • 64% believe natural gas has a long-term role in WA’s energy mix
    • 78% believe the natural gas industry is important to WA’s economy
    • 69% oppose the Greens’ policy to ban all new gas projects
    • 65% oppose Labor forming a minority government with the Greens at the election
    • 69% believe a Labor-Greens minority government would have a negative impact on the WA economy
    • 47% are more likely to vote for a candidate that supports WA’s natural gas industry, while only 15% said they were more likely to vote against a candidate that supported the gas industry (36% said it would not influence their vote).

    Tangney

    • 72% support WA’s natural gas industry
    • 68% believe natural gas has a long-term role in WA’s energy mix, including 54% of Greens voters
    • 80% believe the natural gas industry is important to WA’s economy, including 61% of Greens voters
    • 60% oppose the Greens’ policy to ban all new gas projects, only 12% support it
    • 57% oppose Labor forming a minority government with the Greens at the election
    • 63% believe a Labor-Greens minority government would have a negative impact on the WA economy
    • 48% are more likely to vote for a candidate that supports WA’s natural gas industry, while only 6% said they were more likely to vote against a candidate that supported the gas industry (45% said it would not influence their vote).

    Bullwinkel

    • 77% support WA’s natural gas industry
    • 75% believe natural gas has a long-term role in WA’s energy mix, including 69% of Greens voters
    • 80% believe the natural gas industry is important to WA’s economy, including 85% of Greens voters
    • 74% oppose the Greens’ policy to ban all new gas projects
    • 70% oppose Labor forming a minority government with the Greens at the election
    • 71% believe a Labor-Greens minority government would have a negative impact on the WA economy
    • 46% are more likely to vote for a candidate that supports WA’s natural gas industry, while only 6% said they were more likely to vote against a candidate that supported the gas industry (45% said it would not influence their vote).

    Contact: 0434 631 511

    MIL OSI Economics

  • MIL-OSI Australia: New heights for Queensland’s sustainable aviation fuel industry

    Source: Australian Executive Government Ministers

    A Bundaberg biorefinery that will convert sugar mill waste into sustainable aviation fuel (SAF) and a second project to supply SAF at the Brisbane Airport, are taking off with new funding from the Albanese Labor Government.

    The Australian Renewable Energy Agency (ARENA) is providing $8 million to Australian technology developer Licella to assess the viability of establishing a biorefinery facility in the rum city region.

    It would be co-located with the Isis Central Sugar Mill, which would provide the agricultural residue feedstock.

    If studies prove successful, the biorefinery would be a huge boost for the regional economy and create about 300 construction jobs and 100 ongoing operational roles.

    Meanwhile, Viva Energy will receive $2.4 million to demonstrate the storage and use of SAF within the Brisbane Airport.

    The funding will help recondition a fuel tank at the Pinkenba Terminal to enable blended SAF supply into the airport for commercial use.

    Viva Energy will share its insights with airports across the country, helping ensure airport infrastructure is ready when domestic SAF is available.

    Australia is in a unique position to capitalise on a local industry with readily available biomass feedstock, willing offtake interest and existing expertise with liquid fuels that could combine to address domestic jet fuel demand in the 2020s.

    This renewable fuel could reduce domestic aviation emissions by up to 80% compared to conventional fossil-based fuel, providing a practical and real pathway to net zero for aviation.

    Quotes attributable to Minister for Climate Change and Energy Chris Bowen:

    “This ARENA funding is another demonstration of our government’s commitment for a Future Made in Australia – using our natural resources to build industry, cut emissions from planes, and create real jobs right now.

    “By making more fuel on Australian shores, from Australian renewable energy and feedstock, we can make our fuel supply stronger, cleaner and more secure.”

    Quotes attributable to Minister for Infrastructure, Transport, Regional Development and Local Government Catherine King:

    “The size of our nation means that aviation is often the only option for Australians to get where they need to go.

    “The development of a local sustainable aviation fuel industry is a necessity, but also a huge opportunity for job creation in the regions.” 

    MIL OSI News

  • MIL-OSI: Par Pacific Reports Fourth Quarter and 2024 Results

    Source: GlobeNewswire (MIL-OSI)

    HOUSTON, Feb. 25, 2025 (GLOBE NEWSWIRE) — Par Pacific Holdings, Inc. (NYSE: PARR) (“Par Pacific” or the “Company”) today reported its financial results for the fourth quarter and twelve months ended December 31, 2024.

    • Fourth quarter Net Loss of $(55.7) million, or $(1.01) per diluted share; Adjusted Net Loss of $(43.4) million, or $(0.79) per diluted share; Adjusted EBITDA of $10.9 million
    • Full year net loss of $(33.3) million, or $(0.59) per diluted share; Adjusted Net Income of $21.2 million, or $0.37 per diluted share; Adjusted EBITDA of $238.7 million
    • Record annual Retail and Logistics segment Adjusted EBITDA
    • Repurchased 5 million common shares during 2024, or 9% of year end shares outstanding

    Par Pacific reported a net loss of $(33.3) million, or $(0.59) per diluted share, for the twelve months ended December 31, 2024, compared to net income of $728.6 million, or $11.94 per diluted share, for the twelve months ended December 31, 2023. Adjusted Net Income for 2024 was $21.2 million, compared to $501.2 million for 2023. 2024 Adjusted EBITDA was $238.7 million, compared to $696.2 million for 2023.

    Par Pacific reported a net loss of $(55.7) million, or $(1.01) per diluted share, for the quarter ended December 31, 2024, compared to net income of $289.3 million, or $4.77 per diluted share, for the same quarter in 2023. Fourth quarter 2024 Adjusted Net Loss was $(43.4) million, compared to Adjusted Net Income of $65.2 million in the fourth quarter of 2023. Fourth quarter 2024 Adjusted EBITDA was $10.9 million, compared to $122.0 million in the fourth quarter of 2023. A reconciliation of reported non-GAAP financial measures to their most directly comparable GAAP financial measures can be found in the tables accompanying this news release.

    “Our 2024 results underscore our strategic diversification with strong contribution from Hawaii Refining and record profitability in our Retail and Logistics segments,” said Will Monteleone, President and Chief Executive Officer. “Completing the Montana turnaround prior to the summer driving season and starting up our capital efficient Hawaii Sustainable Aviation Fuel project position us for earnings growth.”

    Refining

    The Refining segment generated operating income of $17.4 million for the year ended December 31, 2024, compared to $676.2 million for the year ended December 31, 2023. Adjusted Gross Margin for the Refining segment in the year ended December 31, 2024 was $618.3 million, compared to $995.0 million in the year ended December 31, 2023.

    Refining segment Adjusted EBITDA for the year ended December 31, 2024 was $139.2 million, compared to $621.5 million for the year ended December 31, 2023.

    The Refining segment reported an operating loss of $(65.4) million in the fourth quarter of 2024, compared to operating income of $174.0 million in the fourth quarter of 2023. Adjusted Gross Margin for the Refining segment was $92.4 million in the fourth quarter of 2024, compared to $227.2 million in the fourth quarter of 2023.

    Refining segment Adjusted EBITDA was $(22.3) million in the fourth quarter of 2024, compared to $106.5 million in the fourth quarter of 2023.

    Hawaii
    The Hawaii Index averaged $5.52 per barrel in the fourth quarter of 2024, compared to $12.48 per barrel in the fourth quarter of 2023. Throughput in the fourth quarter of 2024 was 83 thousand barrels per day (Mbpd), compared to 81 Mbpd for the same quarter in 2023. Production costs were $4.42 per throughput barrel in the fourth quarter of 2024, compared to $4.80 per throughput barrel in the same period of 2023.

    The Hawaii refinery’s Adjusted Gross Margin was $7.36 per barrel during the fourth quarter of 2024, including a net price lag impact of approximately $(5.4) million, or $(0.71) per barrel, compared to $16.73 per barrel during the fourth quarter of 2023.

    Montana
    The Montana Index averaged $5.75 per barrel in the fourth quarter of 2024, compared to $14.80 in the fourth quarter of 2023. The Montana refinery’s throughput in the fourth quarter of 2024 was 52 Mbpd, compared to 50 Mbpd for the same quarter in 2023. Production costs were $10.48 per throughput barrel in the fourth quarter of 2024, compared to $12.03 per throughput barrel in the same period of 2023.

    The Montana refinery’s Adjusted Gross Margin was $3.70 per barrel during the fourth quarter of 2024, compared to $11.55 per barrel during the fourth quarter of 2023.

    Washington
    The Washington Index averaged $(0.62) per barrel in the fourth quarter of 2024, compared to $5.23 per barrel in the fourth quarter of 2023. The Washington refinery’s throughput was 39 Mbpd in the fourth quarter of 2024, compared to 38 Mbpd in the fourth quarter of 2023. Production costs were $4.34 per throughput barrel in the fourth quarter of 2024, compared to $4.53 per throughput barrel in the same period of 2023.

    The Washington refinery’s Adjusted Gross Margin was $1.05 per barrel during the fourth quarter of 2024, compared to $7.87 per barrel during the fourth quarter of 2023.

    Wyoming

    The Wyoming Index averaged $13.36 per barrel in the fourth quarter of 2024, compared to $16.58 per barrel in the fourth quarter of 2023. The Wyoming refinery’s throughput was 14 Mbpd in the fourth quarter of 2024, compared to 17 Mbpd in the fourth quarter of 2023. Production costs were $11.49 per throughput barrel in the fourth quarter of 2024, compared to $8.03 per throughput barrel in the same period of 2023.

    The Wyoming refinery’s Adjusted Gross Margin was $11.11 per barrel during the fourth quarter of 2024, including a FIFO impact of approximately $(2.2) million, or $(1.75) per barrel, compared to $13.90 per barrel during the fourth quarter of 2023.

    Wyoming Refining Operational Update

    The Wyoming refinery experienced an operational incident on the evening of February 12, 2025, and has remained safely idled through the extreme winter weather conditions. We expect to restart the refinery in mid-April at reduced throughput and return to full operations by the end of May.

    Retail

    The Retail segment reported operating income of $64.8 million for the twelve months ended December 31, 2024, compared to $56.6 million in the twelve months ended December 31, 2023. Adjusted Gross Margin for the Retail segment was $164.7 million for the twelve months ended December 31, 2024, compared to $155.3 million in the twelve months ended December 31, 2023.

    For the twelve months ended December 31, 2024, Retail Adjusted EBITDA was $76.0 million, compared to $68.3 million for the twelve months ended December 31, 2023. For the twelve months ended December 31, 2024, the Retail segment reported fuel sales volumes of 121.5 million gallons, compared to 117.6 million gallons for the twelve months ended December 31, 2023. 2024 same store fuel volumes and inside sales revenue increased by 2.2% and 4.6%, respectively, compared to 2023.

    The Retail segment reported operating income of $19.5 million in the fourth quarter of 2024, compared to $14.6 million in the fourth quarter of 2023. Adjusted Gross Margin for the Retail segment was $43.4 million in the fourth quarter of 2024, compared to $40.5 million in the same quarter of 2023.

    Retail segment Adjusted EBITDA was $22.2 million in the fourth quarter of 2024, compared to $17.2 million in the fourth quarter of 2023. The Retail segment reported sales volumes of 30.3 million gallons in the fourth quarter of 2024, compared to 29.8 million gallons in the same quarter of 2023. Fourth quarter 2024 same store fuel volumes and inside sales revenue increased by 2.1% and 6.2%, respectively, compared to fourth quarter of 2023.

    Logistics

    The Logistics segment generated operating income of $89.4 million for the twelve months ended December 31, 2024, compared to $69.7 million for the twelve months ended December 31, 2023. Adjusted Gross Margin for the Logistics segment was $135.8 million for the twelve months ended December 31, 2024, compared to $121.2 million for the twelve months ended December 31, 2023.

    Adjusted EBITDA for the Logistics segment was $120.2 million for the twelve months ended December 31, 2024, compared to $96.7 million for the twelve months ended December 31, 2023.

    The Logistics segment reported operating income of $24.8 million in the fourth quarter of 2024, compared to $15.7 million in the fourth quarter of 2023. Adjusted Gross Margin for the Logistics segment was $36.8 million in the fourth quarter of 2024, compared to $35.3 million in the same quarter of 2023.

    Logistics segment Adjusted EBITDA was $33.0 million in the fourth quarter of 2024, compared to $24.0 million in the fourth quarter of 2023.

    Liquidity

    Net cash provided by operations totaled $83.8 million for the twelve months ended December 31, 2024, including working capital outflows of $(18.1) million and deferred turnaround expenditures of $(73.5) million. Excluding these items, net cash provided by operations totaled $175.3 million for the twelve months ended December 31, 2024. Net cash provided by operations totaled $579.2 million for the twelve months ended December 31, 2023.

    Net cash used in operations totaled $(15.5) million for the three months ended December 31, 2024, including working capital inflows of $19.9 million and deferred turnaround expenditures of $(15.7) million. Excluding these items, net cash used in operations totaled $(19.6) million for the three months ended December 31, 2024. Net cash used in operations totaled $(2.3) million for the three months ended December 31, 2023.

    Net cash used in investing activities totaled $(47.7) million and $(134.0) million for the three months and twelve months ended December 31, 2024, respectively, compared to $(27.3) million and $(659.0) million for the three months and twelve months ended December 31, 2023, respectively. Net cash used in investing activities for the three months and twelve months ended December 31, 2024, includes $(47.7) million and $(135.5) million in capital expenditures, respectively.

    Net cash provided by (used in) financing activities totaled $72.1 million and $(37.0) million for the three months and twelve months ended December 31, 2024, respectively, compared to net cash used in financing activities of $(56.6) million and $(135.6) million for the three months and twelve months ended December 31, 2023, respectively.

    At December 31, 2024, Par Pacific’s cash balance totaled $191.9 million, gross term debt was $644.2 million, and total liquidity was $613.7 million. Net term debt was $452.3 million at December 31, 2024. In February 2025, the Company’s Board of Directors authorized management to repurchase up to $250 million of common stock, with no specified end date. This replaces the prior authorization to repurchase up to $250 million of common stock.

    Laramie Energy

    In conjunction with Laramie Energy LLC’s (“Laramie’s”) refinancing and subsequent cash distribution to Par Pacific during the first quarter of 2023, we resumed the application of equity method accounting for our investment in Laramie effective February 21, 2023.

    During the three and twelve months ended December 31, 2024, we recorded $(3.2) million and $(0.3) million of equity losses. Laramie’s total net loss was $(11.3) million in the fourth quarter of 2024, including unrealized losses on derivatives of $(5.2) million, compared to net income of $42.5 million in the fourth quarter of 2023. Laramie’s total net loss was $(15.5) million during the twelve months ended December 31, 2024, including unrealized losses on derivatives of $(3.6) million, compared to net income of $96.6 million during the twelve months ended December 31, 2023.

    Laramie’s total Adjusted EBITDAX was $11.0 million and $45.8 million for the three and twelve months ended December 31, 2024, respectively, compared to $19.6 million and $89.7 million for the three and twelve months ended December 31, 2023, respectively.

    Laramie’s balance sheet position is strong with $68.6 million of cash and $160.0 million of debt at December 31, 2024. Laramie’s 2024 production was 96.6 million cubic feet of gas equivalent per day (MMcfe/d) and its management team plans to run a one-rig program throughout 2025. Approximately 79% of Laramie’s 2025 production is hedged at $3.20 per million British thermal unit (MMBtu).

    Conference Call Information

    A conference call is scheduled for Wednesday, February 26, 2025 at 9:00 a.m. Central Time (10:00 a.m. Eastern Time). To access the call, please dial 1-833-974-2377 inside the U.S. or 1-412-317-5782 outside of the U.S. and ask for the Par Pacific call. Please dial in at least 10 minutes early to register. The webcast may be accessed online through the Company’s website at http://www.parpacific.com on the Investors page. A telephone replay will be available until March 12, 2025, and may be accessed by calling 1-877-344-7529 inside the U.S. or 1-412-317-0088 outside the U.S. and using the conference ID 2219355.

    About Par Pacific

    Par Pacific Holdings, Inc. (NYSE: PARR), headquartered in Houston, Texas, is a growing energy company providing both renewable and conventional fuels to the western United States. Par Pacific owns and operates 219,000 bpd of combined refining capacity across four locations in Hawaii, the Pacific Northwest and the Rockies, and an extensive energy infrastructure network, including 13 million barrels of storage, and marine, rail, rack, and pipeline assets. In addition, Par Pacific operates the Hele retail brand in Hawaii and the “nomnom” convenience store chain in the Pacific Northwest. Par Pacific also owns 46% of Laramie Energy, LLC, a natural gas production company with operations and assets concentrated in Western Colorado. More information is available at www.parpacific.com

    Forward-Looking Statements

    This news release (and oral statements regarding the subject matter of this news release, including those made on the conference call and webcast announced herein) includes certain “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended, which 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 are forward-looking statements. Forward-looking statements include, without limitation, statements about: expected market conditions; anticipated free cash flows; anticipated refinery throughput; anticipated cost savings; anticipated capital expenditures, including major maintenance costs, and their effect on our financial and operating results, including earnings per share and free cash flow; anticipated retail sales volumes and on-island sales; the anticipated financial and operational results of Laramie Energy, LLC; the amount of our discounted net cash flows and the impact of our NOL carryforwards thereon; our ability to identify, acquire, and develop energy, related retailing, and infrastructure businesses; the timing and expected results of certain development projects, as well as the impact of such investments on our product mix and sales; the anticipated synergies and other benefits of the Billings refinery and associated marketing and logistics assets (“Billings Acquisition”), including renewable growth opportunities, the anticipated financial and operating results of the Billings Acquisition and the effect on Par Pacific’s cash flows and profitability (including Adjusted EBITDA and Adjusted Net Income and Free Cash Flow per share); and other risks and uncertainties detailed in our Annual Report on Form 10-K, Quarterly Reports on Form 10-Q and any other documents that we file with the Securities and Exchange Commission. Additionally, forward-looking statements are subject to certain risks, trends, and uncertainties, such as changes to our financial condition and liquidity; the volatility of crude oil and refined product prices; the Russia-Ukraine war, Israel-Palestine conflict, Houthi attacks in the Red Sea, Iranian activities in the Strait of Hormuz and their potential impacts on global crude oil markets and our business; operating disruptions at our refineries resulting from unplanned maintenance events or natural disasters; environmental risks; changes in the labor market; and risks of political or regulatory changes. We cannot provide assurances that the assumptions upon which these forward-looking statements are based will prove to have been correct. Should any of these risks materialize, or should underlying assumptions prove incorrect, actual results may vary materially from those expressed or implied in any forward-looking statements, and investors are cautioned not to place undue reliance on these forward-looking statements, which are current only as of this date. We do not intend to update or revise any forward-looking statements made herein or any other forward-looking statements as a result of new information, future events, or otherwise. We further expressly disclaim any written or oral statements made by a third party regarding the subject matter of this news release.

    Contact:
    Ashimi Patel
    VP, Investor Relations & Sustainability
    (832) 916-3355
    apatel@parpacific.com

    Condensed Consolidated Statements of Operations
    (Unaudited)
    (in thousands, except per share data)

      Three Months Ended December 31,   Year Ended December 31,
        2024       2023       2024       2023  
    Revenues $ 1,832,221     $ 2,183,511     $ 7,974,457     $ 8,231,955  
    Operating expenses              
    Cost of revenues (excluding depreciation)   1,678,273       1,799,898       7,101,148       6,838,109  
    Operating expense (excluding depreciation)   139,893       155,441       584,282       485,587  
    Depreciation and amortization   34,911       31,943       131,590       119,830  
    General and administrative expense (excluding depreciation)   21,522       25,299       108,844       91,447  
    Equity losses (earnings) from refining and logistics investments   941       (7,485 )     (11,905 )     (11,844 )
    Acquisition and integration costs   32       269       100       17,482  
    Par West redevelopment and other costs   3,500       2,907       12,548       11,397  
    Loss (gain) on sale of assets, net   108       (59 )     222       (59 )
    Total operating expenses   1,879,180       2,008,213       7,926,829       7,551,949  
    Operating income (loss)   (46,959 )     175,298       47,628       680,006  
    Other income (expense)              
    Interest expense and financing costs, net   (21,073 )     (20,476 )     (82,793 )     (72,450 )
    Debt extinguishment and commitment costs   (270 )     (1,500 )     (1,688 )     (19,182 )
    Other loss, net   (422 )     (354 )     (1,869 )     (53 )
    Equity earnings (losses) from Laramie Energy, LLC   (3,163 )     14,279       (296 )     24,985  
    Total other expense, net   (24,928 )     (8,051 )     (86,646 )     (66,700 )
    Income (loss) before income taxes   (71,887 )     167,247       (39,018 )     613,306  
    Income tax benefit (expense)   16,192       122,077       5,696       115,336  
    Net income (loss) $ (55,695 )   $ 289,324     $ (33,322 )   $ 728,642  
    Weighted-average shares outstanding              
    Basic   55,252       59,403       56,775       60,035  
    Diluted   55,252       60,609       56,775       61,014  
                   
    Income (loss) per share              
    Basic $ (1.01 )   $ 4.87     $ (0.59 )   $ 12.14  
    Diluted $ (1.01 )   $ 4.77     $ (0.59 )   $ 11.94  
                                   

    Balance Sheet Data
    (Unaudited)
    (in thousands)

      December 31, 2024   December 31, 2023
    Balance Sheet Data      
    Cash and cash equivalents $         191,921           $         279,107        
    Working capital (1)           488,940                     190,042        
    ABL Credit Facility           483,000                     115,000        
    Term debt (2)           644,233                     550,621        
    Total debt, including current portion           1,112,967                     650,858        
    Total stockholders’ equity           1,191,302                     1,335,424        
               

    _______________________________________

    (1) Working capital is calculated as (i) total current assets excluding cash and cash equivalents less (ii) total current liabilities excluding current portion of long-term debt. Total current assets include inventories stated at the lower of cost or net realizable value.
    (2) Term debt includes the Term Loan Credit Agreement and other long-term debt.
       

    Operating Statistics

    The following table summarizes key operational data:

      Three Months Ended December 31,   Year Ended December 31,
        2024       2023       2024       2023  
    Total Refining Segment              
    Feedstocks throughput (Mbpd) (1)   187.8       186.0       186.7       170.3  
    Refined product sales volume (Mbpd) (1)   199.4       194.4       199.9       183.1  
                   
    Hawaii Refinery              
    Feedstocks throughput (Mbpd)   83.3       80.6       81.1       80.8  
                   
    Yield (% of total throughput)              
    Gasoline and gasoline blendstocks   27.0 %     25.2 %     26.2 %     26.3 %
    Distillates   41.1 %     39.3 %     38.9 %     40.4 %
    Fuel oils   29.2 %     31.8 %     31.3 %     28.9 %
    Other products (0.2)%   (0.2)%     0.2 %     1.1 %
    Total yield   97.1 %     96.1 %     96.6 %     96.7 %
                   
    Refined product sales volume (Mbpd)   93.7       89.0       89.3       89.1  
                   
    Adjusted Gross Margin per bbl ($/throughput bbl) (2) $ 7.36     $ 16.73     $ 9.34     $ 15.25  
    Production costs per bbl ($/throughput bbl) (3)   4.42       4.80       4.58       4.57  
    D&A per bbl ($/throughput bbl)   0.32       0.54       0.43       0.65  
                   
    Montana Refinery              
    Feedstocks Throughput (Mbpd) (1)   51.9       49.8       49.9       54.4  
                   
    Yield (% of total throughput)              
    Gasoline and gasoline blendstocks   43.9 %     45.1 %     48.0 %     48.1 %
    Distillates   32.7 %     38.8 %     31.9 %     32.0 %
    Asphalt   15.2 %     8.7 %     10.9 %     12.1 %
    Other products   2.7 %     2.5 %     3.9 %     3.2 %
    Total yield   94.5 %     95.1 %     94.7 %     95.4 %
                   
    Refined product sales volume (Mbpd) (1)   52.9       51.5       53.2       58.6  
                   
    Adjusted Gross Margin per bbl ($/throughput bbl) (2) $ 3.70     $ 11.55     $ 11.37     $ 21.14  
    Production costs per bbl ($/throughput bbl) (3)   10.48       12.03       12.42       10.78  
    D&A per bbl ($/throughput bbl)   2.26       1.10       1.83       1.45  
                   
      Three Months Ended December 31,   Year Ended December 31,
        2024       2023       2024       2023  
    Washington Refinery              
    Feedstocks throughput (Mbpd)   39.0       38.4       38.2       40.0  
                   
    Yield (% of total throughput)              
    Gasoline and gasoline blendstocks   23.6 %     23.8 %     23.9 %     23.5 %
    Distillate   34.6 %     34.1 %     34.5 %     34.5 %
    Asphalt   19.4 %     20.6 %     18.8 %     19.7 %
    Other products   19.3 %     18.6 %     19.3 %     18.7 %
    Total yield   96.9 %     97.1 %     96.5 %     96.4 %
                   
    Refined product sales volume (Mbpd)   37.9       37.0       39.2       41.7  
                   
    Adjusted Gross Margin per bbl ($/throughput bbl) (2) $ 1.05     $ 7.87     $ 3.25     $ 9.41  
    Production costs per bbl ($/throughput bbl) (3)   4.34       4.53       4.28       4.12  
    D&A per bbl ($/throughput bbl)   1.91       2.22       1.97       1.91  
                   
    Wyoming Refinery              
    Feedstocks throughput (Mbpd)   13.6       17.2       17.5       17.6  
                   
    Yield (% of total throughput)              
    Gasoline and gasoline blendstocks   51.5 %     50.3 %     46.9 %     47.1 %
    Distillate   43.1 %     45.0 %     47.1 %     46.7 %
    Fuel oils   1.7 %     2.3 %     2.4 %     2.5 %
    Other products   1.7 %     1.0 %     2.1 %     1.5 %
    Total yield   98.0 %     98.6 %     98.5 %     97.8 %
                   
    Refined product sales volume (Mbpd)   14.9       16.9       18.2       17.9  
                   
    Adjusted Gross Margin per bbl ($/throughput bbl) (2) $ 11.11     $ 13.90     $ 13.73     $ 25.15  
    Production costs per bbl ($/throughput bbl) (3)   11.49       8.03       8.10       7.50  
    D&A per bbl ($/throughput bbl)   3.55       2.71       2.71       2.69  
                   
                   
    Par Pacific Indices ($ per barrel)              
    Hawaii Index (4) $ 5.52     $ 12.48     $ 7.21     $ 13.06  
    Montana Index (5)   5.75       14.80       14.39       23.71  
    Washington Index (6)   (0.62 )     5.23       4.13       9.81  
    Wyoming Index (7)   13.36       16.58       16.47       24.48  
                   
    Market Cracks ($ per barrel)              
    Singapore 3.1.2 Product Crack (4) $ 11.69     $ 19.44     $ 13.36     $ 19.50  
    Montana 6.3.2.1 Product Crack (5)   15.31       23.56       21.59       30.15  
    Washington 3.1.1.1 Product Crack (6)   8.29       10.83       12.11       17.91  
    Wyoming 2.1.1 Product Crack (7)   16.00       18.70       18.48       27.52  
                   
    Crude Oil Prices ($ per barrel) (8)              
    Brent $ 74.01     $ 82.85     $ 79.86     $ 82.17  
    WTI   70.32       78.53       75.76       77.60  
    ANS (-) Brent   1.00       2.21       1.55       0.95  
    Bakken Guernsey (-) WTI   (1.22 )     (2.20 )     (1.26 )     (0.65 )
    Bakken Williston (-) WTI   (2.54 )     (2.50 )     (2.45 )     (0.09 )
    WCS Hardisty (-) WTI   (12.27 )     (22.78 )     (13.90 )     (17.92 )
    MSW (-) WTI   (3.68 )     (7.34 )     (4.03 )     (3.70 )
    Syncrude (-) WTI   (0.42 )     (4.12 )     0.18       1.32  
    Brent M1-M3   0.74       1.01       1.10       0.81  
                   
    Retail Segment              
    Retail sales volumes (thousands of gallons)   30,287       29,840       121,473       117,550  

    _______________________________________

    (1) Feedstocks throughput and sales volumes per day for the Montana refinery for the three months and year ended December 31, 2023 are calculated based on the 92 and 214-day periods for which we owned the Montana refinery during the three months and year ended December 31, 2023, respectively. As such, the amounts for the total refining segment represent the sum of the Hawaii, Washington, and Wyoming refineries’ throughput or sales volumes averaged over the three months and year ended December 31, 2023 plus the Montana refinery’s throughput or sales volumes averaged over the periods from October 1, 2023, to December 31, 2023 and June 1, 2023 to December 31, 2023, respectively. The 2024 amounts for the total refining segment represent the sum of the Hawaii, Montana, Washington, and Wyoming refineries’ throughput or sales volumes averaged over the three months and year ended December 31, 2024.
    (2) We calculate Adjusted Gross Margin per barrel by dividing Adjusted Gross Margin by total refining throughput. Adjusted Gross Margin for our Washington refinery is determined under the last-in, first-out (“LIFO”) inventory costing method. Adjusted Gross Margin for our other refineries is determined under the first-in, first-out (“FIFO”) inventory costing method.
    (3) Management uses production costs per barrel to evaluate performance and compare efficiency to other companies in the industry. There are a variety of ways to calculate production costs per barrel; different companies within the industry calculate it in different ways. We calculate production costs per barrel by dividing all direct production costs, which include the costs to run the refineries, including personnel costs, repair and maintenance costs, insurance, utilities, and other miscellaneous costs, by total refining throughput. Our production costs are included in Operating expense (excluding depreciation) on our condensed consolidated statements of operations, which also includes costs related to our bulk marketing operations and severance costs.
    (4) Beginning in 2025, we established the Hawaii Index as a new benchmark for our Hawaii operations. We believe the Hawaii Index, which incorporates market cracks and landed crude differentials, better reflects the key drivers impacting our Hawaii refinery’s financial performance compared to prior reported market indices. The Hawaii Index is calculated as the Singapore 3.1.2 Product Crack, or one part gasoline (RON 92) and two parts distillates (Sing Jet & Sing gasoil) as created from a barrel of Brent crude oil, less the Par Hawaii Refining, LLC (“PHR”) crude differential.
    (5) Beginning in 2025, we established the Montana Index as a new benchmark for our Montana refinery. We believe the Montana Index, which incorporates local market cracks, regional crude oil prices, and management’s estimates for other costs of sales, better reflects the key drivers impacting our Montana refinery’s financial performance compared to prior reported market indices. Beginning in 2025, market cracks have been updated to reflect local market product pricing, which better reflects our Montana refinery’s refined product sales price compared to prior reported market indices. The Montana Index is calculated as the Montana 6.3.2.1 Product Crack less Montana crude costs, less other costs of sales, including inflation-adjusted product delivery costs, yield loss expense, taxes and tariffs, and product discounts. The Montana 6.3.2.1 Product Crack is calculated by taking three parts gasoline (Billings E10 and Spokane E10), two parts distillate (Billings ULSD and Spokane ULSD), and one part asphalt (Rocky Mountain Rail Asphalt) as created from a barrel of WTI crude oil, less 100% of the RVO cost for gasoline and ULSD. Asphalt pricing is lagged by one month. The Montana crude cost is calculated as 60% WCS differential to WTI, 20% MSW differential to WTI, and 20% Syncrude differential to WTI. The Montana crude cost is lagged by three months and includes an inflation-adjusted crude delivery cost. Other costs of sales and crude delivery costs are based on historical averages and management’s estimates.
    (6) Beginning in 2025, we established the Washington Index as a new benchmark for our Washington refinery. We believe the Washington Index, which incorporates local market cracks, regional crude oil prices, and management’s estimates for other costs of sales, better reflects the key drivers impacting our Washington refinery’s financial performance compared to prior reported market indices. Beginning in 2025, market cracks have been updated to reflect local market product pricing, which better reflects our Washington refinery’s refined product sales price compared to prior reported market indices. The Washington Index is calculated as the Washington 3.1.1.1 Product Crack, less Washington crude costs, less other costs of sales, including inflation-adjusted product delivery costs, yield loss expense and state and local taxes. The Washington 3.1.1.1 Product Crack is calculated by taking one part gasoline (Tacoma E10), one part distillate (Tacoma ULSD) and one part secondary products (USGC VGO and Rocky Mountain Rail Asphalt) as created from a barrel of WTI crude oil, less 100% of the RVO cost for gasoline and ULSD. Asphalt pricing is lagged by one month. The Washington crude cost is calculated as 67% Bakken Williston differential to WTI and 33% WCS Hardisty differential to WTI. The Washington crude cost is lagged by one month and includes an inflation-adjusted crude delivery cost. Other costs of sales and crude delivery costs are based on historical averages and management’s estimates.
    (7) Beginning in 2025, we established the Wyoming Index as a new benchmark for our Wyoming refinery. We believe the Wyoming Index, which incorporates local market cracks, regional crude oil prices, and management’s estimates for other costs of sales, better reflects the key drivers impacting our Wyoming refinery’s financial performance compared to prior reported market indices. Beginning in 2025, market cracks have also been updated to reflect local market product pricing, which better reflects our Wyoming refinery’s refined product sales price compared to prior reported market indices. The Wyoming Index is calculated as the Wyoming 2.1.1 Product Crack, less Wyoming crude costs, less other cost of sales, including inflation adjusted product delivery costs and yield loss expense, based on historical averages and management’s estimates. The Wyoming 2.1.1 Product Crack is calculated by taking one part gasoline (Rockies gasoline) and one part distillate (USGC ULSD and USGC Jet) as created from a barrel of WTI crude oil, less 100% of the RVO cost for gasoline and ULSD. The Wyoming crude cost is calculated as the Bakken Guernsey differential to WTI on a one-month lag.
    (8) Beginning in 2025, crude oil prices have been updated and expanded to reflect regional differentials to Brent and WTI, which better reflect our refineries’ feedstock costs compared to prior crude oil pricing.
       

    Non-GAAP Performance Measures

    Management uses certain financial measures to evaluate our operating performance that are considered non-GAAP financial measures. These measures should not be considered in isolation or as substitutes or alternatives to their most directly comparable GAAP financial measures or any other measure of financial performance or liquidity presented in accordance with GAAP. These non-GAAP measures may not be comparable to similarly titled measures used by other companies since each company may define these terms differently.

    We believe Adjusted Gross Margin (as defined below) provides useful information to investors because it eliminates the gross impact of volatile commodity prices and adjusts for certain non-cash items and timing differences created by our inventory financing agreements and lower of cost and net realizable value adjustments to demonstrate the earnings potential of the business before other fixed and variable costs, which are reported separately in Operating expense (excluding depreciation) and Depreciation and amortization. Management uses Adjusted Gross Margin per barrel to evaluate operating performance and compare profitability to other companies in the industry and to industry benchmarks. We believe Adjusted Net Income (Loss) and Adjusted EBITDA (as defined below) are useful supplemental financial measures that allow investors to assess the financial performance of our assets without regard to financing methods, capital structure, or historical cost basis, the ability of our assets to generate cash to pay interest on our indebtedness, and our operating performance and return on invested capital as compared to other companies without regard to financing methods and capital structure. We believe Adjusted EBITDA by segment (as defined below) is a useful supplemental financial measure to evaluate the economic performance of our segments without regard to financing methods, capital structure, or historical cost basis.

    Beginning with financial results reported for the second quarter of 2023, Adjusted Gross Margin, Adjusted Net Income (Loss), and Adjusted EBITDA also exclude our portion of interest, taxes, and depreciation expense from our refining and logistics investments acquired on June 1, 2023, as part of the Billings Acquisition.

    Beginning with financial results reported for the fourth quarter of 2023, Adjusted Gross Margin, Adjusted Net Income (Loss), and Adjusted EBITDA excludes all hedge losses (gains) associated with our Washington ending inventory and LIFO layer increment impacts associated with our Washington inventory. In addition, we have modified our environmental obligation mark-to-market adjustment to include only the mark-to-market losses (gains) associated with our net RINs liability and net obligation associated with the Washington Climate Commitment Act (“Washington CCA”) and Clean Fuel Standard. This modification was made as part of our change in how we estimate our environmental obligation liabilities.

    Beginning with financial results reported for the fourth quarter of 2023, Adjusted Net Income (loss) excludes unrealized interest rate derivative losses (gains) and all Laramie Energy related impacts with the exception of cash distributions. We have recast Adjusted Net Income (Loss) for prior periods when reported to conform to the modified presentation.

    Beginning with financial results reported for the first quarter of 2024, Adjusted Net Income (loss) also excludes other non-operating income and expenses. This modification improves comparability between periods by excluding income and expenses resulting from non-operating activities.

    Effective as of the fourth quarter of 2024, we have modified our definition of Adjusted Gross Margin, Adjusted Net Income (Loss) and Adjusted EBITDA to align the accounting treatment for deferred turnaround costs from our refining and logistics investments with our accounting policy. Under this approach, we exclude our share of their turnaround expenses, which are recorded as period costs in their financial statements, and instead defer and amortize these costs on a straight-line basis over the period estimated until the next planned turnaround. This modification enhances consistency and comparability across reporting periods.

    Adjusted Gross Margin

    Adjusted Gross Margin is defined as Operating income (loss) excluding:

      operating expense (excluding depreciation);
      depreciation and amortization (“D&A”);
      Par’s portion of interest, taxes, and D&A expense from refining and logistics investments;
      impairment expense;
      loss (gain) on sale of assets, net;
      Par’s portion of accounting policy differences from refining and logistics investments;
      inventory valuation adjustment (which adjusts for timing differences to reflect the economics of our inventory financing agreements, including lower of cost or net realizable value adjustments, the impact of the embedded derivative repurchase or terminal obligations, hedge losses (gains) associated with our Washington ending inventory and intermediation obligation, purchase price allocation adjustments, and LIFO layer increment and decrement impacts associated with our Washington inventory);
      Environmental obligation mark-to-market adjustments (which represents the mark-to-market losses (gains) associated with our net RINs liability and net obligation associated with the Washington CCA and Clean Fuel Standard); and
      unrealized loss (gain) on derivatives.
         

    The following tables present a reconciliation of Adjusted Gross Margin to the most directly comparable GAAP financial measure, operating income (loss), on a historical basis, for selected segments, for the periods indicated (in thousands):

    Three months ended December 31, 2024 Refining   Logistics   Retail
    Operating income (loss) $ (65,399 )   $ 24,772   $ 19,477
    Operating expense (excluding depreciation)   114,706       3,829     21,358
    Depreciation and amortization   24,524       7,140     2,566
    Par’s portion of interest, taxes, and depreciation and amortization expense from refining and logistics investments   456       1,101    
    Inventory valuation adjustment   5,929          
    Environmental obligation mark-to-market adjustments   (937 )        
    Unrealized loss on commodity derivatives   9,220          
    Par’s portion of accounting policy differences from refining and logistics investments   3,856          
    Loss on sale of assets, net   8          
    Adjusted Gross Margin (1) $ 92,363     $ 36,842   $ 43,401
                       
    Three months ended December 31, 2023 Refining   Logistics   Retail
    Operating income $ 174,038     $ 15,709   $ 14,594  
    Operating expense (excluding depreciation)   120,810       11,272     23,359  
    Depreciation and amortization   21,190       7,321     2,885  
    Par’s portion of interest, taxes, and depreciation and amortization expense from refining and logistics investments   765       952      
    Inventory valuation adjustment   (24,089 )          
    Environmental obligation mark-to-market adjustments   (15,672 )          
    Unrealized gain on commodity derivatives   (50,024 )          
    Loss (gain) on sale of assets, net   219           (308 )
    Adjusted Gross Margin (1) (2) $ 227,237     $ 35,254   $ 40,530  
                         
    Year Ended December 31, 2024 Refining   Logistics   Retail
    Operating income $ 17,412     $ 89,351   $ 64,800  
    Operating expense (excluding depreciation)   479,737       15,676     88,869  
    Depreciation and amortization   91,108       27,033     11,037  
    Par’s portion of interest, taxes, and depreciation and amortization expense from refining and logistics investments   2,493       3,651      
    Inventory valuation adjustment   (490 )          
    Environmental obligation mark-to-market adjustments   (19,136 )          
    Unrealized loss on commodity derivatives   43,281            
    Par’s portion of accounting policy differences from refining and logistics investments   3,856            
    Loss (gain) on sale of assets, net   8       124     (10 )
    Adjusted Gross Margin (1) $ 618,269     $ 135,835   $ 164,696  
                         
    Year Ended December 31, 2023 Refining   Logistics   Retail
    Operating income $ 676,161     $ 69,744   $ 56,603  
    Operating expense (excluding depreciation)   373,612       24,450     87,525  
    Depreciation and amortization   81,017       25,122     11,462  
    Par’s portion of interest, taxes, and depreciation and amortization expense from refining and logistics investments   1,586       1,857      
    Inventory valuation adjustment   102,710            
    Environmental obligation mark-to-market adjustments   (189,783 )          
    Unrealized gain on commodity derivatives   (50,511 )          
    Loss (gain) on sale of assets, net   219           (308 )
    Adjusted Gross Margin (1) (2) $ 995,011     $ 121,173   $ 155,282  

    _______________________________________

    (1) For the three months and years ended December 31, 2024 and 2023, there was no impairment expense in Operating income.
    (2) For the three months and year ended December 31, 2023, there was no impact in Operating income from accounting policy differences at our refining and logistics investments.
       

    Adjusted Net Income (Loss) and Adjusted EBITDA

    Adjusted Net Income (Loss) is defined as Net income (loss) excluding:

      inventory valuation adjustment (which adjusts for timing differences to reflect the economics of our inventory financing agreements, including lower of cost or net realizable value adjustments, the impact of the embedded derivative repurchase or terminal obligations, hedge losses (gains) associated with our Washington ending inventory and intermediation obligation, purchase price allocation adjustments, and LIFO layer increment and decrement impacts associated with our Washington inventory);
      Environmental obligation mark-to-market adjustments (which represents the mark-to-market losses (gains) associated with our net RINs liability and net obligation associated with the Washington CCA and Clean Fuel Standard);
      unrealized (gain) loss on derivatives;
      acquisition and integration costs;
      redevelopment and other costs related to Par West;
      debt extinguishment and commitment costs;
      increase in (release of) tax valuation allowance and other deferred tax items;
      changes in the value of contingent consideration and common stock warrants;
      severance costs and other non-operating expense (income);
      (gain) loss on sale of assets;
      impairment expense;
      impairment expense associated with our investment in Laramie Energy;
      Par’s share of equity (earnings) losses from Laramie Energy, LLC, excluding cash distributions; and
      Par’s portion of accounting policy differences from refining and logistics investments.

    Adjusted EBITDA is defined as Adjusted Net Income (Loss) excluding:

      D&A;
      interest expense and financing costs, net, excluding unrealized interest rate derivative loss (gain);
      cash distributions from Laramie Energy, LLC to Par;
      Par’s portion of interest, taxes, and D&A expense from refining and logistics investments; and
      income tax expense (benefit) excluding the increase in (release of) tax valuation allowance.
         

    The following table presents a reconciliation of Adjusted Net Income (Loss) and Adjusted EBITDA to the most directly comparable GAAP financial measure, net income (loss), on a historical basis for the periods indicated (in thousands):        

      Three Months Ended December 31,   Year Ended December 31,
        2024       2023       2024       2023  
    Net income (loss) $ (55,695 )   $ 289,324     $ (33,322 )   $ 728,642  
    Inventory valuation adjustment   5,929       (24,089 )     (490 )     102,710  
    Environmental obligation mark-to-market adjustments   (937 )     (15,672 )     (19,136 )     (189,783 )
    Unrealized loss (gain) on derivatives   8,729       (48,539 )     42,485       (49,690 )
    Acquisition and integration costs   32       269       100       17,482  
    Par West redevelopment and other costs   3,500       2,907       12,548       11,397  
    Debt extinguishment and commitment costs   270       1,500       1,688       19,182  
    Changes in valuation allowance and other deferred tax items (1)   (12,553 )     (126,219 )     (3,315 )     (126,219 )
    Severance costs and other non-operating expense (2)   154       100       14,802       1,785  
    Loss (gain) on sale of assets, net   108       (59 )     222       (59 )
    Equity (earnings) losses from Laramie Energy, LLC, excluding cash distributions   3,163       (14,279 )     1,781       (14,279 )
    Par’s portion of accounting policy differences from refining and logistics investments   3,856             3,856        
    Adjusted Net Income (Loss) (3) (4)   (43,444 )     65,243       21,219       501,168  
    Depreciation and amortization   34,911       31,943       131,590       119,830  
    Interest expense and financing costs, net, excluding unrealized interest rate derivative loss (gain)   21,564       18,991       83,589       71,629  
    Laramie Energy, LLC cash distributions to Par               (1,485 )     (10,706 )
    Par’s portion of interest, taxes, and depreciation and amortization expense from refining and logistics investments   1,557       1,717       6,144       3,443  
    Income tax expense (benefit)   (3,639 )     4,142       (2,381 )     10,883  
    Adjusted EBITDA (3) $ 10,949     $ 122,036     $ 238,676     $ 696,247  

    _______________________________________

    (1) For the three months and year ended December 31, 2024, we recognized a non-cash deferred tax benefit of $12.6 million and $3.3 million, respectively. This tax benefit is included in Income tax expense (benefit) on our consolidated statements of operations. For the three months and year ended December 31, 2023, we recognized a non-cash deferred tax benefit of $126.2 million primarily related to the release of a majority of the valuation allowance against our federal net deferred tax assets.
    (2) For the year ended December 31, 2024, we incurred $13.1 million of stock-based compensation expenses associated with accelerated vesting of equity awards and modification of vested equity awards related to our CEO transition and $0.8 million for a legal settlement unrelated to current operating activities.
    (3) For the three months and years ended December 31, 2024 and 2023, there was no change in value of contingent consideration, change in value of common stock warrants, impairment expense, impairments associated with our investment in Laramie Energy, or our share of Laramie Energy’s asset impairment losses in excess of our basis difference. Please read the Non-GAAP Performance Measures discussion above for information regarding changes to the components of Adjusted Net Income (Loss) and Adjusted EBITDA made during the reporting periods.
    (4) For the three months and year ended December 31, 2023, there was no impact in Operating income from accounting policy differences at our refining and logistics investments.
       

     

    The following table sets forth the computation of basic and diluted Adjusted Net Income (Loss) per share (in thousands, except per share amounts):

      Three Months Ended December 31,   Year Ended December 31,
        2024       2023     2024     2023
    Adjusted Net Income (Loss) $ (43,444 )   $ 65,243   $ 21,219   $ 501,168
    Plus: effect of convertible securities                
    Numerator for diluted income (loss) per common share $ (43,444 )   $ 65,243   $ 21,219   $ 501,168
                   
    Basic weighted-average common stock shares outstanding   55,252       59,403     56,775     60,035
    Add dilutive effects of common stock equivalents (1)         1,206     657     979
    Diluted weighted-average common stock shares outstanding   55,252       60,609     57,432     61,014
                   
    Basic Adjusted Net Income (Loss) per common share $ (0.79 )   $ 1.10   $ 0.37   $ 8.35
    Diluted Adjusted Net Income (Loss) per common share $ (0.79 )   $ 1.08   $ 0.37   $ 8.21

    _______________________________________

    (1) Entities with a net loss from continuing operations are prohibited from including potential common shares in the computation of diluted per share amounts. We have utilized the basic shares outstanding to calculate both basic and diluted Adjusted Net Loss per common share for the three months ended December 31, 2024.
       

    Adjusted EBITDA by Segment

    Adjusted EBITDA by segment is defined as Operating income (loss) excluding:

      D&A;
      inventory valuation adjustment (which adjusts for timing differences to reflect the economics of our inventory financing agreements, including lower of cost or net realizable value adjustments, the impact of the embedded derivative repurchase or terminal obligations, hedge losses (gains) associated with our Washington ending inventory and intermediation obligation, purchase price allocation adjustments, and LIFO layer increment and decrement impacts associated with our Washington inventory);
      Environmental obligation mark-to-market adjustments (which represents the mark-to-market losses (gains) associated with our net RINs liability and net obligation associated with the Washington CCA and Clean Fuel Standard);
      unrealized (gain) loss on derivatives;
      acquisition and integration costs;
      redevelopment and other costs related to Par West;
      severance costs and other non-operating expense (income);
      (gain) loss on sale of assets;
      impairment expense;
      Par’s portion of interest, taxes, and D&A expense from refining and logistics investments; and
      Par’s portion of accounting policy differences from refining and logistics investments.
         

    Adjusted EBITDA by segment also includes Gain on curtailment of pension obligation and Other income (loss), net, which are presented below operating income (loss) on our condensed consolidated statements of operations.

    The following table presents a reconciliation of Adjusted EBITDA by segment to the most directly comparable GAAP financial measure, operating income (loss) by segment, on a historical basis, for selected segments, for the periods indicated (in thousands):

      Three Months Ended December 31, 2024
      Refining   Logistics   Retail   Corporate and Other
    Operating income (loss) by segment $ (65,399 )   $ 24,772   $ 19,477   $ (25,809 )
    Depreciation and amortization   24,524       7,140     2,566     681  
    Inventory valuation adjustment   5,929                
    Environmental obligation mark-to-market adjustments   (937 )              
    Unrealized loss on commodity derivatives   9,220                
    Acquisition and integration costs                 32  
    Par West redevelopment and other costs                 3,500  
    Severance costs and other non-operating expense             154      
    Par’s portion of accounting policy differences from refining and logistics investments   3,856                
    Loss on sale of assets, net   8               100  
    Par’s portion of interest, taxes, depreciation and amortization expense from refining and logistics investments   456       1,101          
    Other loss, net                 (422 )
    Adjusted EBITDA (1) $ (22,343 )   $ 33,013   $ 22,197   $ (21,918 )
                               
      Three Months Ended December 31, 2023
      Refining   Logistics   Retail   Corporate and Other
    Operating income (loss) by segment $ 174,038     $ 15,709   $ 14,594     $ (29,043 )
    Depreciation and amortization   21,190       7,321     2,885       547  
    Inventory valuation adjustment   (24,089 )                
    Environmental obligation mark-to-market adjustments   (15,672 )                
    Unrealized gain on commodity derivatives   (50,024 )                
    Acquisition and integration costs                   269  
    Par West redevelopment and other costs                   2,907  
    Severance costs and other non-operating expenses   100                  
    Loss (gain) on sale of assets, net   219           (308 )     30  
    Par’s portion of interest, taxes, depreciation and amortization expense from refining and logistics investments   765       952            
    Other loss, net                   (354 )
    Adjusted EBITDA (1) (2) $ 106,527     $ 23,982   $ 17,171     $ (25,644 )
                                 
      Year Ended December 31, 2024
      Refining   Logistics   Retail   Corporate and Other
    Operating income (loss) by segment $ 17,412     $ 89,351   $ 64,800     $ (123,935 )
    Depreciation and amortization   91,108       27,033     11,037       2,412  
    Inventory valuation adjustment   (490 )                
    Environmental obligation mark-to-market adjustments   (19,136 )                
    Unrealized loss on commodity derivatives   43,281                  
    Acquisition and integration costs                   100  
    Severance costs and other non-operating expenses   642           154       14,006  
    Par West redevelopment and other costs                   12,548  
    Par’s portion of accounting policy differences from refining and logistics investments   3,856                  
    Loss (gain) on sale of assets, net   8       124     (10 )     100  
    Par’s portion of interest, taxes, depreciation and amortization expense from refining and logistics investments   2,493       3,651            
    Other loss, net                   (1,869 )
    Adjusted EBITDA (1) $ 139,174     $ 120,159   $ 75,981     $ (96,638 )
                                 
      Year Ended December 31, 2023
      Refining   Logistics   Retail   Corporate and Other
    Operating income (loss) by segment $         676,161             $         69,744           $         56,603             $         (122,502 )
    Depreciation and amortization           81,017                       25,122                     11,462                       2,229          
    Inventory valuation adjustment           102,710                       —                     —                       —          
    Environmental obligation mark-to-market adjustments           (189,783 )             —                     —                       —          
    Unrealized gain on commodity derivatives           (50,511 )             —                     —                       —          
    Acquisition and integration costs           —                       —                     —                       17,482          
    Severance costs and other non-operating expenses           100                       —                     580                       1,105          
    Par West redevelopment and other costs           —                       —                     —                       11,397          
    Loss (gain) on sale of assets, net           219                       —                     (308 )             30          
    Par’s portion of interest, taxes, depreciation and amortization expense from refining and logistics investments           1,586                       1,857                     —                       —          
    Other loss, net           —                       —                     —                       (53 )
    Adjusted EBITDA (1) (2) $         621,499             $         96,723           $         68,337             $         (90,312 )

    _______________________________________

    (1) For the three months and years ended December 31, 2024 and 2023, there was no change in value of contingent consideration, change in value of common stock warrants, impairment expense, impairments associated with our investment in Laramie Energy, or our share of Laramie Energy’s asset impairment losses in excess of our basis difference.
    (2) For the three months and year ended December 31, 2023, there was no impact in Operating income (loss) from accounting policy differences at our refining and logistics investments.
       

    Laramie Energy Adjusted EBITDAX

    Adjusted EBITDAX is defined as net income (loss) excluding commodity derivative loss (gain), loss (gain) on settled derivative instruments, interest expense, gain on extinguishment of debt, non-cash preferred dividend, depreciation, depletion, amortization, and accretion, exploration and geological and geographical expense, bonus accrual, equity-based compensation expense, loss (gain) on disposal of assets, phantom units, and expired acreage (non-cash). We believe Adjusted EBITDAX is a useful supplemental financial measure to evaluate the economic and operational performance of exploration and production companies such as Laramie Energy.

    The following table presents a reconciliation of Laramie Energy’s Adjusted EBITDAX to the most directly comparable GAAP financial measure, net income (loss) for the periods indicated (in thousands):

      Three Months Ended December 31,   Year Ended December 31,
        2024       2023       2024       2023  
    Net income (loss) $ (11,250 )   $ 42,538     $ (15,546 )   $ 96,586  
    Commodity derivative (income) loss   4,766       (40,338 )     (11,055 )     (73,289 )
    Loss on settled derivative instruments   389       1,594       14,609       161  
    Interest expense and loan fees   4,845       5,366       20,628       20,108  
    Gain on extinguishment of debt                     6,644  
    Non-cash preferred dividend                     2,910  
    Depreciation, depletion, amortization, and accretion   8,158       7,714       32,841       30,179  
    Phantom units   3,328       2,325       2,825       5,496  
    Loss (gain) on sale of assets, net               (8 )     307  
    Expired acreage (non-cash)   770       441       1,492       553  
    Total Adjusted EBITDAX (1) $ 11,006     $ 19,640     $ 45,786     $ 89,655  

    _______________________________________

    (1) For the three months and years ended December 31, 2024 and 2023, there was no exploration and geological and geographical expense, bonus accrual, or equity-based compensation expense.

    The MIL Network

  • MIL-OSI: Range Announces Fourth Quarter 2024 Results and Three-Year Outlook

    Source: GlobeNewswire (MIL-OSI)

    FORT WORTH, Texas, Feb. 25, 2025 (GLOBE NEWSWIRE) — RANGE RESOURCES CORPORATION (NYSE: RRC) today announced its fourth quarter 2024 financial results, plans for 2025, and a three-year outlook through 2027.

    Full-Year 2024 Highlights –

    • Cash flow from operating activities of $945 million
    • Cash flow from operations, before working capital changes, of $1.1 billion
    • Reduced net debt by $172 million, returned $77 million in dividends, and invested $65 million in share repurchases
    • Production averaged 2.18 Bcfe per day, approximately 68% natural gas
    • All-in capital spending of $654 million, or $0.82 per mcfe
    • Pre-hedge NGL realizations of $25.77 per barrel – premium of $2.33 over the Mont Belvieu equivalent
    • Proved reserves of 18.1 Tcfe with positive performance revisions for 17th consecutive year
    • Debt to EBITDAX of 1.2x (Non-GAAP) at year-end 2024
    • Expect to achieve Net Zero for 2024 Scope 1 and 2 GHG emissions
    • Maintenance capital improved by ~$50 million on strong well performance and infrastructure optimization

    Dennis Degner, the Company’s CEO, commented, “Last year demonstrated the resilience of Range’s business as we successfully generated free cash flow, returned capital to shareholders and met our long-term balance sheet target. We did this despite natural gas prices being at cycle lows and while strategically investing in the business. Over the last two years, Range has made countercyclical investments to build in-process well inventory, which supports our targeted, efficient production growth plans through 2027. Importantly, we have contracted natural gas transportation to support our plans and Range will utilize new NGL export capacity towards the same premium markets that have benefited Range shareholders for many years.

    An exciting chapter for U.S. natural gas is materializing as export capacity is commissioned to meet growing global gas demand. As the lowest-cost, lowest-emissions natural gas basin in the country, we expect Appalachia will play a significant role to meet global gas needs over time. We believe Range will see an outsized benefit given our proven, high-quality Marcellus inventory with duration measured in decades, our access to markets with growing demand and our advantaged full-cycle cost structure that provides the foundation for delivering through-cycle returns for shareholders.”

    2025 Capital and Production Guidance

    Range’s 2025 all-in capital budget is expected to be $650 to $690 million, which consists of:

    • Approximately $530 million of all-in maintenance capital including land and facilities
    • $70 – $100 million drilling and completion capital for future growth
    • Up to $30 million on targeted acreage which increases planned lateral lengths and future inventory
    • Approximately $20 – $30 million for pneumatic devices and facility upgrades

    Range’s development plan for 2025 will target annual production of approximately 2.2 Bcfe per day. Consistent with 2024, Range plans to run two drilling rigs and one frac crew resulting in modest production growth in 2025 while building additional in-process well inventory for increased growth capacity in 2026 and 2027. Up to $30 million is planned for investment in non-maintenance acreage to support increased lateral lengths and incremental inventory. Approximately $20 – $30 million is planned for pneumatic devices and production facility upgrades, part of a $50 – $60 million project expected to be completed by year-end 2026 to further reduce emissions, with $10 million of the total project already completed in 2024.

    The table below summarizes 2024 activity and expected 2025 plans regarding the number of wells to sales in each area. To maintain current production levels, Range will turn to sales approximately 600,000 lateral feet in a year.

      Planned Wells
    TIL in 2025
      Wells TIL in
    2024
       
    SW PA Super-Rich 14   9
    SW PA Wet 23   21
    SW PA Dry 5   12
    NE PA Dry 4   2
    Total Appalachia 46   44

    Three-Year Outlook

    Range’s three-year outlook targets a 2027 daily production level of 2.6 Bcfe, an increase of approximately 400 Mmcfe per day compared to 2024, with annual estimated capital expenditures ranging between $650 to $700 million over the next three years. Annual capital spending is expected to represent a reinvestment rate below 50%, assuming $3.75 natural gas. Through 2027, Range expects to have maintained its 30+ years of core Marcellus inventory to support additional growth and meet future demand. Alternatively, at the end of this production profile, Range could maintain 2.6 Bcfe per day of production with approximately $570 million of annual drilling and completion capital, the equivalent of approximately $0.60 per mcfe.

    Marketing and Transportation Update

    Supporting Range’s planned production, the Company has secured the following incremental transportation, processing, and export capacity, all of which are expected to start in 2026:

    • 300 Mmcf per day of processing capacity at the Harmon Creek facility
    • 250 Mmcf per day of gas transportation, accessing expected demand growth in Midwest and Gulf Coast markets
    • 20,000 bbl per day of NGL takeaway and export capacity utilizing a new East Coast terminal

    Financial Discussion

    Except for generally accepted accounting principles (“GAAP”) reported amounts, specific expense categories exclude non-cash impairments, unrealized mark-to-market adjustment on derivatives, non-cash stock compensation and other items shown separately on the attached tables. “Unit costs” as used in this release are composed of direct operating, transportation, gathering, processing and compression, taxes other than income, general and administrative, interest and depletion, depreciation and amortization costs divided by production. See “Non-GAAP Financial Measures” for a definition of non-GAAP financial measures and the accompanying tables that reconcile each non-GAAP measure to its most directly comparable GAAP financial measure.

    Fourth Quarter 2024 Results

    GAAP revenues and other income for fourth quarter 2024 totaled $626 million, GAAP net cash provided from operating activities (including changes in working capital) was $218 million, and GAAP net income was $95 million ($0.39 per diluted share).  Fourth quarter earnings results include a $54 million mark-to-market derivative loss due to increases in commodity prices.

    Cash flow from operations before changes in working capital, a non-GAAP measure, was $312 million.  Adjusted net income comparable to analysts’ estimates, a non-GAAP measure, was $164 million ($0.68 per diluted share) in fourth quarter 2024.

    The following table details Range’s fourth quarter 2024 unit costs per mcfe(a):

    Expenses   4Q 2024 
    (per mcfe)
      4Q 2023 
    (per mcfe)
      Increase
    (Decrease)

                 
    Direct operating (a)   $ 0.12   $ 0.11   9%
    Transportation, gathering, processing and compression (a)   1.48   1.39   6%
    Taxes other than income   0.03   0.02   50%
    General and administrative (a)   0.18   0.17   6%
    Interest expense (a)   0.14   0.14   0%
    Total cash unit costs (b)   1.94   1.83   6%
    Depletion, depreciation and amortization (DD&A)   0.46   0.45   2%
    Total unit costs plus DD&A(b)   $ 2.40   $ 2.28   5%
                 

    (a)   Excludes stock-based compensation, one-time settlements, and amortization of deferred financing costs.
    (b)   Totals may not be exact due to rounding.

    The following table details Range’s average production and realized pricing for fourth quarter 2024(a):

      4Q24 Production & Realized Pricing
      Natural Gas
    (mcf)
      Oil
    (bbl)
      NGLs 
    (bbl)
       Natural Gas 
    Equivalent
    (mcfe)
                 
                     
    Net production per day 1,505,140   5,028   111,199   2,202,500  
                     
    Average NYMEX price $ 2.80   $70.28   $ 24.47      
    Differential, including basis hedging (0.44)   (10.64)   1.96      
    Realized prices before NYMEX hedges 2.36   59.64   26.43   3.08  
    Settled NYMEX hedges 0.54   11.01   0.04   0.40  
    Average realized prices after hedges $ 2.90   $ 70.66   $ 26.47   $ 3.48  
                   

    (a)   Totals may not be exact due to rounding

    Fourth quarter 2024 natural gas, NGLs and oil price realizations (including the impact of cash-settled hedges and derivative settlements) averaged $3.48 per mcfe.

    • The average natural gas price, including the impact of basis hedging, was $2.36 per mcf, or a ($0.44) per mcf differential to NYMEX. In 2025, Range expects its natural gas differential to be ($0.40) to ($0.48) relative to NYMEX.
    • Range’s pre-hedge NGL price during the quarter was $26.43 per barrel, approximately $1.96 above the Mont Belvieu weighted equivalent. Range’s 2025 NGL differential is expected to be +$0.00 to +$1.25 relative to a Mont Belvieu equivalent barrel.
    • Crude oil and condensate price realizations, before realized hedges, averaged $59.64 per barrel, or $10.64 below WTI (West Texas Intermediate). Range’s 2025 condensate differential is expected to be ($10.00) to ($15.00) relative to NYMEX.

    Capital Expenditures

    Fourth quarter 2024 drilling and completion expenditures were $124 million. In addition, during the quarter, approximately $29 million was invested in acreage leasehold, gathering systems and other. Total 2024 capital budget expenditures were $654 million, including $580 million on drilling and completion, and a combined $74 million on acreage, gathering systems, pneumatic upgrades and other.

    Financial Position and Repurchase Activity

    As of December 31, 2024, Range had net debt outstanding of approximately $1.40 billion, consisting of $1.71 billion of senior notes and $304 million in cash. During the fourth quarter, Range repurchased in the open market $9.4 million principal amount of 4.875% senior notes due 2025 at a discount.

    During the fourth quarter, Range repurchased 650,000 shares at an average price of approximately $32.50. As of year-end, the Company had approximately $1.0 billion of availability under the share repurchase program.

    Range’s Board of Directors expects to approve a 12.5% increase to the quarterly cash dividend to $0.09 per share of the Company’s common stock. Details regarding the record and payment dates for quarterly dividends will be announced as each quarterly dividend is formally declared by the Board.

    2024 Proved Reserves

    Year-end 2024 reserves were similar to last year at 18.1 Tcfe, despite natural gas prices of $2.13 per Mmbtu, reflecting the resilience of Range’s low-cost asset base. Range also recorded its 17th consecutive year of positive performance revisions driven by continued strong results from existing Marcellus producing wells. Proved reserves included 6.2 Tcfe of proved undeveloped reserves from approximately 2.9 million lateral feet scheduled to be developed within the next five years at an expected development cost of $0.38 per mcfe. Proved undeveloped reserves represents approximately 10% of Range’s undeveloped core Marcellus inventory.

    Summary of Changes in Proved Reserves
    (in Bcfe)
    Balance at December 31, 2023 18,113
       
    Extensions, discoveries and additions 749
    Performance revisions 77
    Price revisions (1)
    Sales (11)
    Production (796)
       
    Balance at December 31, 2024 18,131
       

    As shown in the table below, the present value (PV10) of reserves under SEC methodology was $5.5 billion. For comparison, the PV10 using December 31, 2024 strip prices equates to $12.2 billion using the same proven reserve volumes.

      2024 SEC 
    Pricing (a)
    Strip Price
    Average 
    (b)
         
    Natural Gas Price ($/MMBtu) $2.13 $3.54
    WTI Oil Price ($/Bbl) $74.88 $63.62
    NGL Price ($/Bbl) $24.40 $25.21
         
    Proved Reserves PV10 ($ billions) $5.5 $12.2
         

    a)   SEC benchmark prices adjusted for energy content, quality and basis differentials were $1.74 per mcf and $63.39 per barrel of crude oil.
    b)   NYMEX 10-year strip prices adjusted for energy content, quality and basis differentials realized an average gas price differential of ($0.47) and an average realized oil differential of ($12.39) per barrel, which equate to $3.07 per mcf and $51.23 per barrel over the life of the reserves.

    Guidance – 2025

    Capital & Production Guidance

    Range’s 2025 all-in capital budget is $650 million – $690 million. Annual production is expected to be approximately 2.2 Bcfe per day for 2025. Liquids are expected to be over 30% of production.

    Full Year 2025 Expense Guidance

    Direct operating expense: $0.12 – $0.14 per mcfe
    Transportation, gathering, processing and compression expense: $1.50 – $1.55 per mcfe
    Taxes other than income: $0.03 – $0.04 per mcfe
    Exploration expense: $24 – $28 million
    G&A expense: $0.17 – $0.19 per mcfe
    Net Interest expense: $0.12 – $0.13 per mcfe
    DD&A expense: $0.45 – $0.46 per mcfe
    Net brokered gas marketing expense: $8 – $12 million
       

    Full Year 2025 Price Guidance

    Based on recent market indications, Range expects to average the following price differentials for its production in 2025.

    FY 2025 Natural Gas:(1) NYMEX minus $0.40 to $0.48
    FY 2025 Natural Gas Liquids:(2) MB plus $0.00 to $1.25 per barrel
    FY 2025 Oil/Condensate: WTI minus $10.00 to $15.00
       

    (1) Including basis hedging
    (2) Mont Belvieu-equivalent pricing based on weighting of 53% ethane, 27% propane, 8% normal butane, 4% iso-butane and 8% natural gasoline.

    Hedging Status

    Range hedges portions of its expected future production volumes to increase the predictability of cash flow and maintain a strong, flexible financial position. Please see the detailed hedging schedule posted on the Range website under Investor Relations – Financial Information.

    Range has also hedged basis across the Company’s numerous natural gas sales points to limit volatility between benchmark and regional prices. The combined fair value of natural gas basis hedges as of December 31, 2024, was a net loss of $29.2 million.    

    Conference Call Information

    A conference call to review the financial results is scheduled on Wednesday, February 26 at 8:00 AM Central Time (9:00 AM Eastern Time). Please click here to pre-register for the conference call and obtain a dial in number with passcode.

    A simultaneous webcast of the call may be accessed at www.rangeresources.com. The webcast will be archived for replay on the Company’s website until March 26th.

    Non-GAAP Financial Measures

    To supplement the presentation of its financial results prepared in accordance with generally accepted accounting principles (GAAP), the Company’s earnings press release contains certain financial measures that are not presented in accordance with GAAP. Management believes certain non-GAAP measures may provide financial statement users with meaningful supplemental information for comparisons within the industry. These non-GAAP financial measures may include, but are not limited to Net Income, excluding certain items, Cash flow from operations before changes in working capital, realized prices, Net debt and Cash margin.

    Adjusted net income comparable to analysts’ estimates as set forth in this release represents income or loss from operations before income taxes adjusted for certain non-cash items (detailed in the accompanying table) less income taxes. We believe adjusted net income comparable to analysts’ estimates is calculated on the same basis as analysts’ estimates and that many investors use this published research in making investment decisions and evaluating operational trends of the Company and its performance relative to other oil and gas producing companies. Diluted earnings per share (adjusted) as set forth in this release represents adjusted net income comparable to analysts’ estimates on a diluted per share basis. A table is included which reconciles income or loss from operations to adjusted net income comparable to analysts’ estimates and diluted earnings per share (adjusted). On its website, the Company provides additional comparative information on prior periods.

    Cash flow from operations before changes in working capital represents net cash provided by operations before changes in working capital and exploration expense adjusted for certain non-cash compensation items. Cash flow from operations before changes in working capital (sometimes referred to as “adjusted cash flow”) is widely accepted by the investment community as a financial indicator of an oil and gas company’s ability to generate cash to internally fund exploration and development activities and to service debt. Cash flow from operations before changes in working capital is also useful because it is widely used by professional research analysts in valuing, comparing, rating and providing investment recommendations of companies in the oil and gas exploration and production industry. In turn, many investors use this published research in making investment decisions. Cash flow from operations before changes in working capital is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operations, investing, or financing activities as an indicator of cash flows, or as a measure of liquidity. A table is included which reconciles net cash provided by operations to cash flow from operations before changes in working capital as used in this release. On its website, the Company provides additional comparative information on prior periods for cash flow, cash margins and non-GAAP earnings as used in this release.

    The cash prices realized for oil and natural gas production, including the amounts realized on cash-settled derivatives and net of transportation, gathering, processing and compression expense, is a critical component in the Company’s performance tracked by investors and professional research analysts in valuing, comparing, rating and providing investment recommendations and forecasts of companies in the oil and gas exploration and production industry. In turn, many investors use this published research in making investment decisions. Due to the GAAP disclosures of various derivative transactions and third-party transportation, gathering, processing and compression expense, such information is now reported in various lines of the income statement. The Company believes that it is important to furnish a table reflecting the details of the various components of each income statement line to better inform the reader of the details of each amount and provide a summary of the realized cash-settled amounts and third-party transportation, gathering, processing and compression expense, which were historically reported as natural gas, NGLs and oil sales. This information is intended to bridge the gap between various readers’ understanding and fully disclose the information needed.

    Net debt is calculated as total debt less cash and cash equivalents. The Company believes this measure is helpful to investors and industry analysts who utilize Net debt for comparative purposes across the industry.

    The Company discloses in this release the detailed components of many of the single line items shown in the GAAP financial statements included in the Company’s Annual or Quarterly Reports on Form 10-K or 10-Q. The Company believes that it is important to furnish this detail of the various components comprising each line of the Statements of Operations to better inform the reader of the details of each amount, the changes between periods and the effect on its financial results.

    We believe that the presentation of PV10 value of our proved reserves is a relevant and useful metric for our investors as supplemental disclosure to the standardized measure, or after-tax amount, because it presents the discounted future net cash flows attributable to our proved reserves before taking into account future corporate income taxes and our current tax structure. While the standardized measure is dependent on the unique tax situation of each company, PV10 is based on prices and discount factors that are consistent for all companies. Because of this, PV10 can be used within the industry and by credit and security analysts to evaluate estimated net cash flows from proved reserves on a more comparable basis.

    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.

    Included within this release are certain “forward-looking statements” within the meaning of the federal securities laws, including the safe harbor provisions of the Private Securities Litigation Reform Act of 1995, that are not limited to historical facts, but reflect Range’s current beliefs, expectations or intentions regarding future events.  Words such as “may,” “will,” “could,” “should,” “expect,” “plan,” “project,” “intend,” “anticipate,” “believe,” “outlook”, “estimate,” “predict,” “potential,” “pursue,” “target,” “continue,” and similar expressions are intended to identify such forward-looking statements.

    All statements, except for statements of historical fact, made within regarding activities, events or developments the Company expects, believes or anticipates will or may occur in the future, such as those regarding future well costs, expected asset sales, well productivity, future liquidity and financial resilience, anticipated exports and related financial impact, NGL market supply and demand, future commodity fundamentals and pricing, future capital efficiencies, future shareholder value, emerging plays, capital spending, anticipated drilling and completion activity, acreage prospectivity, expected pipeline utilization and future guidance information, are forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. These statements are based on assumptions and estimates that management believes are reasonable based on currently available information; however, management’s assumptions and Range’s future performance are subject to a wide range of business risks and uncertainties and there is no assurance that these goals and projections can or will be met. Any number of factors could cause actual results to differ materially from those in the forward-looking statements. Further information on risks and uncertainties is available in Range’s filings with the Securities and Exchange Commission (SEC), including its most recent Annual Report on Form 10-K. Unless required by law, Range undertakes no obligation to publicly update or revise any forward-looking statements to reflect circumstances or events after the date they are made.

    The SEC permits oil and gas companies, in filings made with the SEC, to disclose proved reserves, which are estimates that geological and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under existing economic and operating conditions as well as the option to disclose probable and possible reserves. Range has elected not to disclose its probable and possible reserves in its filings with the SEC. Range uses certain broader terms such as “resource potential,” “unrisked resource potential,” “unproved resource potential” or “upside” or other descriptions of volumes of resources potentially recoverable through additional drilling or recovery techniques that may include probable and possible reserves as defined by the SEC’s guidelines. Range has not attempted to distinguish probable and possible reserves from these broader classifications. The SEC’s rules prohibit us from including in filings with the SEC these broader classifications of reserves. These estimates are by their nature more speculative than estimates of proved, probable and possible reserves and accordingly are subject to substantially greater risk of actually being realized. Unproved resource potential refers to Range’s internal estimates of hydrocarbon quantities that may be potentially discovered through exploratory drilling or recovered with additional drilling or recovery techniques and have not been reviewed by independent engineers. Unproved resource potential does not constitute reserves within the meaning of the Society of Petroleum Engineer’s Petroleum Resource Management System and does not include proved reserves. Area wide unproven resource potential has not been fully risked by Range’s management. “EUR”, or estimated ultimate recovery, refers to our management’s estimates of hydrocarbon quantities that may be recovered from a well completed as a producer in the area. These quantities may not necessarily constitute or represent reserves within the meaning of the Society of Petroleum Engineer’s Petroleum Resource Management System or the SEC’s oil and natural gas disclosure rules. Actual quantities that may be recovered from Range’s interests could differ substantially. Factors affecting ultimate recovery include the scope of Range’s drilling program, which will be directly affected by the availability of capital, drilling and production costs, commodity prices, availability of drilling services and equipment, drilling results, lease expirations, transportation constraints, regulatory approvals, field spacing rules, recoveries of gas in place, length of horizontal laterals, actual drilling results, including geological and mechanical factors affecting recovery rates and other factors. Estimates of resource potential may change significantly as development of our resource plays provides additional data.

    In addition, our production forecasts and expectations for future periods are dependent upon many assumptions, including estimates of production decline rates from existing wells and the undertaking and outcome of future drilling activity, which may be affected by significant commodity price or drilling cost changes. Investors are urged to consider closely the disclosure in our most recent Annual Report on Form 10-K, available from our website at www.rangeresources.com or by written request to 100 Throckmorton Street, Suite 1200, Fort Worth, Texas 76102. You can also obtain this Form 10-K on the SEC’s website at www.sec.gov or by calling the SEC at 1-800-SEC-0330.

    SOURCE: Range Resources Corporation

    Range Investor Contacts:

    Laith Sando
    817-869-4267

    Matt Schmid
    817-869-1538

    Range Media Contact:

    Mark Windle
    724-873-3223

    RANGE RESOURCES CORPORATION
                                       
                                       
    STATEMENTS OF INCOME
    Based on GAAP reported earnings with additional
    details of items included in each line in Form 10-K
    (Unaudited, In thousands, except per share data)
      Three Months Ended December 31,     Twelve Months Ended December 31,  
      2024     2023     %     2024     2023     %  
    Revenues and other income:                                  
    Natural gas, NGLs and oil sales (a) $ 635,122     $ 603,279           $ 2,213,850     $ 2,334,661        
    Derivative fair value (loss) income   (53,804 )     291,059             56,726       821,154        
    Brokered natural gas and marketing   41,535       44,460             133,048       206,552        
    ARO settlement (loss) gain (b)         2             (26 )     1        
    Interest income (b)   3,144       1,921             12,651       5,937        
    Gain on sale of assets (b)   89       101             311       454        
    Other (b)   331       636             524       6,113        
    Total revenues and other income   626,417       941,458     -33 %     2,417,084       3,374,872     -28 %
                                       
    Costs and expenses:                                  
    Direct operating   24,655       22,200             93,399       94,362        
    Direct operating – stock-based compensation (c)   468       443             1,922       1,723        
    Transportation, gathering, processing and compression   299,401       283,061             1,177,925       1,113,941        
    Taxes other than income   6,166       4,083             21,625       23,726        
    Brokered natural gas and marketing   41,655       44,319             138,080       200,789        
    Brokered natural gas and marketing – stock-based compensation (c)   603       491             2,465       2,095        
    Exploration   7,983       7,193             25,489       25,280        
    Exploration – stock-based compensation (c)   349       315             1,354       1,250        
    Abandonment and impairment of unproved properties   (201 )     2,051             8,417       46,359        
    General and administrative   35,485       34,472             133,303       127,838        
    General and administrative – stock-based compensation (c)   10,905       9,389             38,004       35,850        
    General and administrative – lawsuit settlements   91       114             782       1,052        
    General and administrative – bad debt expense   50                   50              
    Exit costs   9,156       28,279             37,214       99,940        
    Deferred compensation plan (d)   3,878       (2,953 )           9,593       26,593        
    Interest expense   27,911       28,734             113,341       118,620        
    Interest expense – amortization of deferred financing costs (e)   1,357       1,352             5,417       5,384        
    (Gain) loss on early extinguishment of debt   (3 )     1             (257 )     (438 )      
    Depletion, depreciation and amortization   92,484       90,968             358,356       350,165        
    Total costs and expenses   562,393       554,512     1 %     2,166,479       2,274,529     -5 %
                                       
    Income before income taxes   64,024       386,946     -83 %     250,605       1,100,343     -77 %
                                       
    Income tax (benefit) expense                                  
    Current   2,902       (1,453 )           8,165       1,547        
    Deferred   (33,720 )     78,365             (23,900 )     227,654        
        (30,818 )     76,912             (15,735 )     229,201        
                                       
    Net income $ 94,842     $ 310,034     -69 %   $ 266,340     $ 871,142     -69 %
                                       
                                       
    Net income Per Common Share                                  
    Basic $ 0.39     $ 1.29           $ 1.10     $ 3.61        
    Diluted $ 0.39     $ 1.27           $ 1.09     $ 3.57        
                                       
    Weighted average common shares outstanding, as reported                                  
    Basic   240,300       238,833     1 %     240,689       236,986     2 %
    Diluted   242,355       241,735     0 %     242,745       239,837     1 %
                                       
                                       
    (a) See separate natural gas, NGLs and oil sales information table.  
    (b) Included in Other income in the 10-K.  
    (c) Costs associated with stock compensation and restricted stock amortization, which have been reflected  
        in the categories associated with the direct personnel costs, which are combined with the cash costs in the 10-K.  
    (d) Reflects the change in market value of the vested Company stock held in the deferred compensation plan.  
    (e) Included in interest expense in the 10-K.  
       
    RANGE RESOURCES CORPORATION
               
               
    BALANCE SHEET     
    (In thousands) December 31,     December 31,  
      2024     2023  
      (Audited)     (Audited)  
    Assets          
    Current assets $ 636,982     $ 528,794  
    Derivative assets   87,098       442,971  
    Natural gas and oil properties, successful efforts method   6,421,700       6,117,681  
    Other property and equipment   2,465       1,696  
    Operating lease right-of-use assets   119,838       23,821  
    Other   79,592       88,922  
      $ 7,347,675     $ 7,203,885  
               
    Liabilities and Stockholders’ Equity          
    Current liabilities $ 1,263,247     $ 580,469  
    Asset retirement obligations   1,189       2,395  
    Derivative liabilities   9,634       222  
    Senior notes $ 1,089,614       1,774,229  
    Deferred tax liabilities   541,378       561,288  
    Derivative liabilities   10,488       107  
    Deferred compensation liabilities   65,233       72,976  
    Operating lease liabilities   35,737       16,064  
    Asset retirement obligations and other liabilities   137,181       119,896  
    Divestiture contract obligation   257,317       310,688  
        3,411,018       3,438,334  
               
    Common stock and retained deficit   4,449,987       4,213,585  
    Other comprehensive income   611       647  
    Common stock held in treasury   (513,941 )     (448,681 )
    Total stockholders’ equity   3,936,657       3,765,551  
      $ 7,347,675     $ 7,203,885  
                   
    RECONCILIATION OF TOTAL DEBT AS REPORTED
    TO NET DEBT, a non-GAAP measure
    (Unaudited, in thousands)
      December 31,     December 31,        
      2024     2023     %  
                     
    Total debt, net of deferred financing costs, as reported $ 1,697,883     $ 1,774,229     -4 %
    Unamortized debt issuance costs, as reported   10,819       14,159        
    Less cash and cash equivalents, as reported   (304,490 )     (211,974 )      
    Net debt, a non-GAAP measure $ 1,404,212     $ 1,576,414     -11 %
                         
    RANGE RESOURCES CORPORATION
                           
                           
                           
                           
    CASH FLOWS FROM OPERATING ACTIVITIES           
    (Unaudited, in thousands)           
                           
      Three Months Ended
    December 31,
        Twelve Months Ended
    December 31,
     
      2024     2023     2024     2023  
                           
    Net income   94,842       310,034       266,340       871,142  
    Adjustments to reconcile net cash provided from continuing operations:                      
    Deferred income tax (benefit) expense   (33,720 )     78,365       (23,900 )     227,654  
    Depletion, depreciation and amortization   92,484       90,968       358,356       350,165  
    Abandonment and impairment of unproved properties   (201 )     2,051       8,417       46,359  
    Derivative fair value loss (income)   53,804       (291,059 )     (56,726 )     (821,154 )
    Cash settlements on derivative financial instruments   69,697       65,018       432,392       253,514  
    Divestiture contract obligation, including accretion   9,155       28,215       37,088       99,595  
    Allowance for bad debts   50             50        
    Amortization of deferred financing costs and other   1,174       1,144       4,526       4,735  
    Deferred and stock-based compensation   16,267       7,683       53,864       67,849  
    Gain on sale of assets   (89 )     (101 )     (311 )     (454 )
    (Gain) loss on early extinguishment of debt   (3 )     1       (257 )     (438 )
                           
    Changes in working capital:                      
    Accounts receivable   (121,116 )     (65,334 )     (19,586 )     223,081  
    Other current assets   5,485       8,235       3,676       (1,285 )
    Accounts payable   26,609       7,234       (443 )     (77,057 )
    Accrued liabilities and other   3,452       (16,359 )     (118,972 )     (265,814 )
    Net changes in working capital   (85,570 )     (66,224 )     (135,325 )     (121,075 )
    Net cash provided from operating activities   217,890       226,095       944,514       977,892  
                           
                           
                           
    RECONCILIATION OF NET CASH PROVIDED FROM OPERATING           
    ACTIVITIES, AS REPORTED, TO CASH FLOW FROM OPERATIONS           
    BEFORE CHANGES IN WORKING CAPITAL, a non-GAAP measure           
    (Unaudited, in thousands)           
      Three Months Ended
    December 31,
        Twelve Months Ended
    December 31,
     
      2024     2023     2024     2023  
    Net cash provided from operating activities, as reported $ 217,890     $ 226,095     $ 944,514     $ 977,892  
    Net changes in working capital   85,570       66,224       135,325       121,075  
    Exploration expense   7,983       7,193       25,489       25,280  
    Lawsuit settlements   91       114       782       1,052  
    Non-cash compensation adjustment and other   120       272       517       655  
    Cash flow from operations before changes in working capital – non-GAAP measure $ 311,654     $ 299,898     $ 1,106,627     $ 1,125,954  
                           
                           
                           
    ADJUSTED WEIGHTED AVERAGE SHARES OUTSTANDING
    (Unaudited, in thousands)
      Three Months Ended
    December 31,
        Twelve Months Ended
    December 31,
     
      2024     2023     2024     2023  
    Basic:                      
    Weighted average shares outstanding   241,112       241,258       241,868       241,130  
    Stock held by deferred compensation plan   (812 )     (2,425 )     (1,179 )     (4,144 )
    Adjusted basic   240,300       238,833       240,689       236,986  
                           
    Dilutive:                      
    Weighted average shares outstanding   241,112       241,258       241,868       241,130  
    Dilutive stock options under treasury method   1,243       477       877       (1,293 )
    Adjusted dilutive   242,355       241,735       242,745       239,837  
                                   
    RANGE RESOURCES CORPORATION
                                       
    RECONCILIATION OF NATURAL GAS, NGLs AND OIL SALES
    AND DERIVATIVE FAIR VALUE INCOME (LOSS) TO
    CALCULATED CASH REALIZED NATURAL GAS, NGLs AND
    OIL PRICES WITH AND WITHOUT THIRD-PARTY
    TRANSPORTATION, GATHERING, PROCESSING AND
    COMPRESSION COSTS, a non-GAAP measure
    (Unaudited, In thousands, except per unit data)
      Three Months Ended December 31,     Twelve Months Ended December 31,  
      2024     2023     %     2024     2023     %  
    Natural gas, NGLs and Oil Sales components:                                  
    Natural gas sales $ 337,176     $ 320,393           $ 1,052,442     $ 1,234,308        
    NGLs sales   270,356       238,423             1,020,903       933,791        
    Oil sales   27,590       44,463             140,505       166,562        
    Total Natural Gas, NGLs and Oil Sales, as reported $ 635,122     $ 603,279     5 %   $ 2,213,850     $ 2,334,661     -5 %
                                       
    Derivative Fair Value (Loss) Income, as reported $ (53,804 )   $ 291,059           $ 56,726     $ 821,154        
    Cash settlements on derivative financial instruments – (gain) loss:                                  
    Natural gas   (64,169 )     (59,846 )           (419,199 )     (256,693 )      
    NGLs   (433 )                 (3,743 )            
    Oil   (5,095 )     2,828             (9,450 )     11,179        
    Contingent consideration – divestiture         (8,000 )                 (8,000 )      
    Total change in fair value related to commodity derivatives prior to                                  
    settlement, a non GAAP measure $ (123,501 )   $ 226,041           $ (375,666 )   $ 567,640        
                                       
    Transportation, gathering, processing and compression components:                                  
    Natural Gas $ 155,483     $ 152,058           $ 611,698     $ 588,970        
    NGLs   143,294       130,833             564,269       524,114        
    Oil   624       170             1,958       857        
    Total transportation, gathering, processing and compression, as reported $ 299,401     $ 283,061           $ 1,177,925     $ 1,113,941        
                                       
    Natural gas, NGL and Oil sales, including cash-settled derivatives: (c)                                  
    Natural gas sales $ 401,345     $ 380,239           $ 1,471,641     $ 1,491,001        
    NGLs sales   270,789       238,423             1,024,646       933,791        
    Oil Sales   32,685       41,635             149,955       155,383        
    Total $ 704,819     $ 660,297     7 %   $ 2,646,242     $ 2,580,175     3 %
                                       
    Production of natural gas, NGLs and oil during the periods (a):                                  
    Natural Gas (mcf)   138,472,888       141,716,744     -2 %     545,415,974       538,084,671     1 %
    NGLs (bbls)   10,230,284       9,571,519     7 %     39,622,576       37,939,700     4 %
    Oil (bbls)   462,570       656,533     -30 %     2,180,528       2,475,306     -12 %
    Gas equivalent (mcfe) (b)   202,630,012       203,085,056     0 %     796,234,598       780,574,707     2 %
                                       
    Production of natural gas, NGLs and oil – average per day (a):                                  
    Natural Gas (mcf)   1,505,140       1,540,399     -2 %     1,490,208       1,474,205     1 %
    NGLs (bbls)   111,199       104,038     7 %     108,258       103,944     4 %
    Oil (bbls)   5,028       7,136     -30 %     5,958       6,782     -12 %
    Gas equivalent (mcfe) (b)   2,202,500       2,207,446     0 %     2,175,504       2,138,561     2 %
                                       
    Average prices, excluding derivative settlements and before third-party                                  
    transportation costs:                                  
    Natural Gas (per mcf) $ 2.43     $ 2.26     8 %   $ 1.93     $ 2.29     -16 %
    NGLs (per bbl) $ 26.43     $ 24.91     6 %   $ 25.77     $ 24.61     5 %
    Oil (per bbl) $ 59.64     $ 67.72     -12 %   $ 64.44     $ 67.29     -4 %
    Gas equivalent (per mcfe) (b) $ 3.13     $ 2.97     5 %   $ 2.78     $ 2.99     -7 %
                                       
    Average prices, including derivative settlements before third-party                                  
    transportation costs: (c)                                  
    Natural Gas (per mcf) $ 2.90     $ 2.68     8 %   $ 2.70     $ 2.77     -3 %
    NGLs (per bbl) $ 26.47     $ 24.91     6 %   $ 25.86     $ 24.61     5 %
    Oil (per bbl) $ 70.66     $ 63.42     11 %   $ 68.77     $ 62.77     10 %
    Gas equivalent (per mcfe) (b) $ 3.48     $ 3.25     7 %   $ 3.32     $ 3.31     0 %
                                       
    Average prices, including derivative settlements and after third-party                                  
    transportation costs: (d)                                  
    Natural Gas (per mcf) $ 1.78     $ 1.61     11 %   $ 1.58     $ 1.68     -6 %
    NGLs (per bbl) $ 12.46     $ 11.24     11 %   $ 11.62     $ 10.80     8 %
    Oil (per bbl) $ 69.31     $ 63.16     10 %   $ 67.87     $ 62.43     9 %
    Gas equivalent (per mcfe) (b) $ 2.00     $ 1.86     8 %   $ 1.84     $ 1.88     -2 %
                                       
    Transportation, gathering and compression expense per mcfe $ 1.48     $ 1.39     6 %   $ 1.48     $ 1.43     3 %
                                       
    (a) Represents volumes sold regardless of when produced. 
    (b) Oil and NGLs are converted at the rate of one barrel equals six mcfe based upon the approximate relative energy content of oil to natural gas, which is not necessarily 
        indicative of the relationship of oil and natural gas prices. 
    (c) Excluding third-party transportation, gathering, processing and compression costs. 
    (d) Net of transportation, gathering, processing and compression costs. 
    RANGE RESOURCES CORPORATION
                                       
    RECONCILIATION OF INCOME BEFORE INCOME
    TAXES AS REPORTED TO INCOME BEFORE INCOME TAXES
    EXCLUDING CERTAIN ITEMS, a non-GAAP measure
    (Unaudited, In thousands, except per share data)
      Three Months Ended
    December 31,
        Twelve Months Ended
    December 31,
     
      2024     2023     %     2024     2023     %  
                                       
    Income from operations before income taxes, as reported   64,024       386,946       -83 %     250,605       1,100,343      -77 %
    Adjustment for certain special items:                                  
    Gain on the sale of assets   (89 )     (101 )           (311 )     (454 )      
    ARO settlement loss (gain)         (2 )           26       (1 )      
    Change in fair value related to derivatives prior to settlement   123,501       (226,041 )           375,666       (567,640 )      
    Abandonment and impairment of unproved properties   (201 )     2,051             8,417       46,359        
    (Gain) loss on early extinguishment of debt   (3 )     1             (257 )     (438 )      
    Lawsuit settlements   91       114             782       1,052        
    Exit costs   9,156       28,279             37,214       99,940        
    Brokered natural gas and marketing – stock-based compensation   603       491             2,465       2,095        
    Direct operating – stock-based compensation   468       443             1,922       1,723        
    Exploration expenses – stock-based compensation   349       315             1,354       1,250        
    General & administrative – stock-based compensation   10,905       9,389             38,004       35,850        
    Deferred compensation plan – non-cash adjustment   3,878       (2,953 )           9,593       26,593        
                                       
    Income before income taxes, as adjusted   212,682       198,932       7 %     725,480       746,672     -3 %
                                       
    Income tax expense (benefit), as adjusted                                  
    Current (a)   2,902       (1,453 )           8,165       1,547        
    Deferred (a)   46,015       47,208             158,696       170,189        
                                       
    Net income, excluding certain items, a non-GAAP measure $ 163,765     $ 153,177       7 %   $ 558,619     $ 574,936     -3 %
                                       
    Non-GAAP income per common share                                  
    Basic $ 0.68     $ 0.64       6 %   $ 2.32     $ 2.43     -5 %
    Diluted $ 0.68     $ 0.63       8 %   $ 2.30     $ 2.40     -4 %
                                       
    Non-GAAP diluted shares outstanding, if dilutive   242,355       241,735             242,745       239,837        
                                       
                                       
                                       
                                       
                                       
    (a) Taxes are estimated to be approximately 23% for 2023 and 2024  
    RANGE RESOURCES CORPORATION
                           
                           
                           
    RECONCILIATION OF NET INCOME, EXCLUDING           
    CERTAIN ITEMS AND ADJUSTED EARNINGS PER           
    SHARE, non-GAAP measures           
    (In thousands, except per share data)           
      Three Months Ended
    December 31,
        Twelve Months Ended
    December 31,
     
      2024     2023     2024     2023  
                           
    Net income, as reported $ 94,842     $ 310,034     $ 266,340     $ 871,142  
    Adjustments for certain special items:                      
    Gain on the sale of assets   (89 )     (101 )     (311 )     (454 )
    ARO settlement loss (gain)         (2 )     26       (1 )
    (Gain) loss on early extinguishment of debt   (3 )     1       (257 )     (438 )
    Change in fair value related to derivatives prior to settlement   123,501       (226,041 )     375,666       (567,640 )
    Abandonment and impairment of unproved properties   (201 )     2,051       8,417       46,359  
    Lawsuit settlements   91       114       782       1,052  
    Exit costs   9,156       28,279       37,214       99,940  
    Stock-based compensation   12,325       10,638       43,745       40,918  
    Deferred compensation plan   3,878       (2,953 )     9,593       26,593  
    Tax impact   (79,735 )     31,157       (182,596 )     57,465  
                           
    Net income, excluding certain items, a non-GAAP measure $ 163,765     $ 153,177     $ 558,619     $ 574,936  
                           
    Net income per diluted share, as reported $ 0.39     $ 1.27     $ 1.09     $ 3.57  
    Adjustments for certain special items per diluted share:                      
    Gain on the sale of assets                      
    ARO settlement loss (gain)                      
    (Gain) loss on early extinguishment of debt                      
    Change in fair value related to derivatives prior to settlement   0.51       (0.94 )     1.55       (2.37 )
    Abandonment and impairment of unproved properties         0.01       0.03       0.19  
    Lawsuit settlements                      
    Exit costs   0.04       0.12       0.15       0.42  
    Stock-based compensation   0.05       0.04       0.18       0.17  
    Deferred compensation plan   0.02       (0.01 )     0.04       0.11  
    Adjustment for rounding differences               0.01       0.01  
    Tax impact   (0.33 )     0.13       (0.75 )     0.24  
    Dilutive share impact (rabbi trust and other)         0.01             0.06  
                           
    Net income per diluted share, excluding certain items, a non-GAAP measure $ 0.68     $ 0.63     $ 2.30     $ 2.40  
                           
    Adjusted earnings per share, a non-GAAP measure:                      
    Basic $ 0.68     $ 0.64     $ 2.32     $ 2.43  
    Diluted $ 0.68     $ 0.63     $ 2.30     $ 2.40  
                                   
    RANGE RESOURCES CORPORATION
                         
    RECONCILIATION OF CASH MARGIN PER MCFE, a non-
    GAAP measure
    (Unaudited, In thousands, except per unit data)
      Three Months Ended
    December 31,
        Twelve Months Ended
    December 31,
      2024     2023     2024     2023
    Revenues                    
    Natural gas, NGLs and oil sales, as reported $ 635,122     $ 603,279     $ 2,213,850     $ 2,334,661  
    Derivative fair value (loss) income, as reported   (53,804 )     291,059       56,726       821,154  
    Less non-cash fair value loss (gain)   123,501       (226,041 )     375,666       (567,640 )
    Brokered natural gas and marketing, as reported   41,535       44,460       133,048       206,552  
    Other income, as reported   3,564       2,660       13,460       12,505  
    Less gain on sale of assets   (89 )     (101 )     (311 )     (454
    Less ARO settlement         (2 )     26       (1 )
    Cash revenues   749,829       715,314       2,792,465       2,806,777  
                         
    Expenses                    
    Direct operating, as reported   25,123       22,643       95,321       96,085  
    Less direct operating stock-based compensation   (468 )     (443 )     (1,922 )     (1,723 )
    Transportation, gathering and compression, as reported   299,401       283,061       1,177,925       1,113,941  
    Taxes other than income, as reported   6,166       4,083       21,625       23,726  
    Brokered natural gas and marketing, as reported   42,258       44,810       140,545       202,884  
    Less brokered natural gas and marketing stock-based compensation   (603 )     (491 )     (2,465 )     (2,095
    General and administrative, as reported   46,531       43,975       172,139       164,740  
    Less G&A stock-based compensation   (10,905 )     (9,389 )     (38,004 )     (35,850 )
    Less lawsuit settlements   (91 )     (114 )     (782 )     (1,052 )
    Less bad debt expense   (50 )           (50 )      
    Interest expense, as reported   29,268       30,086       118,758       124,004  
    Less amortization of deferred financing costs   (1,357 )     (1,352 )     (5,417 )     (5,384 )
    Cash expenses   435,273       416,869       1,677,673       1,679,276  
                         
    Cash margin, a non-GAAP measure $ 314,556     $ 298,445     $ 1,114,792     $ 1,127,501  
                         
    Mmcfe produced during period   202,630       203,085       796,235       780,575  
                         
    Cash margin per mcfe $ 1.55     $ 1.47     $ 1.40     $ 1.44  
                         
    RECONCILIATION OF INCOME BEFORE INCOME TAXES          
    TO CASH MARGIN, a non-GAAP measure          
    (Unaudited, in thousands, except per unit data)          
      Three Months Ended
    December 31,
        Twelve Months Ended
    December 31,
      2024     2023     2024     2023
                         
    Income before income taxes, as reported $ 64,024     $ 386,946     $ 250,605     $ 1,100,343  
    Adjustments to reconcile income before income taxes                    
    to cash margin:                    
    ARO settlements         (2 )     26       (1 )
    Derivative fair value loss (income)   53,804       (291,059 )     (56,726 )     (821,154 )
    Net cash receipts on derivative settlements   69,697       65,018       432,392       253,514  
    Exploration expense   7,983       7,193       25,489       25,280  
    Lawsuit settlements   91       114       782       1,052  
    Exit costs   9,156       28,279       37,214       99,940  
    Deferred compensation plan   3,878       (2,953 )     9,593       26,593  
    Stock-based compensation (direct operating, brokered natural gas and   12,325       10,638       43,745       40,918  
    marketing and general and administrative)                    
    Bad debt expense   50             50        
    Interest – amortization of deferred financing costs   1,357       1,352       5,417       5,384  
    Depletion, depreciation and amortization   92,484       90,968       358,356       350,165  
    Gain on sale of assets   (89 )     (101 )     (311 )     (454 )
    (Gain) loss on early extinguishment of debt   (3 )     1       (257 )     (438 )
    Abandonment and impairment of unproved properties   (201 )     2,051       8,417       46,359  
    Cash margin, a non-GAAP measure $ 314,556     $ 298,445     $ 1,114,792     $ 1,127,501  

    The MIL Network

  • MIL-OSI New Zealand: Business and Energy – Winter ‘24 hedging costs impact interim financial result – Meridian

    Source: Meridian Energy

    26 February 2025 – Meridian Energy has reported a net loss after tax of $121 million for the six months ending 31 December 2024, compared to a net profit after tax of $191 million in last year’s interim result. 

    Operating cash flows were $50 million, down from $303 million in the same period last year. 
    These results were heavily impacted by the cost of hedge contracts for winter 2024 in the face of one-in-90-year record low inflows and an unexpected and unprecedented shortage of domestic gas. The hedge contracts included calling the largest demand response option with New Zealand’s Aluminum Smelter (NZAS).

    EBITDAF fell from $443 million to $257 million and underlying net profit fell from $175 million to a $5 million loss. Both of these are non-GAAP measures.

    “The combination of particularly low hydro inflows, low wind and gas shortages made the operating environment for the first half of this financial year as tough as I can recall experiencing,” says Meridian Chief Executive Neal Barclay.

    “We took a hit for New Zealand. Meridian put this country’s security of supply first and, as New Zealand’s largest renewable electricity generator, our balance sheet tends to underwrite the mitigation of extended droughts. That’s one of the ways the country benefits from having large and financially strong gentailers. While the situation was particularly challenging, we know we rely on Mother Nature for our fuel and accept the financial impact droughts bring. We prepare the business to deal with these kinds of eventualities, including maintaining a strong and flexible balance sheet.”

    “There is plenty of time before the coming winter, but we are highly focused on managing risks to winter 2025 security. We have reached a new agreement with NZAS for them to reduce demand by 50MW and are looking for simple rule changes to access this country’s existing contingent hydro storage. The bigger issue, though, is the structural and significant shortage of domestic gas. New Zealand needs to take urgent action to address this. Gas is the biggest factor in setting spot and future electricity prices,” says Neal Barclay.

    With a challenging first half to the financial year, the Meridian Board has decided to maintain the interim dividend at the same level as the prior period, and declared an interim ordinary dividend of 6.15 cents per share. The dividend reinvestment plan will apply to this interim dividend at a 2% discount.

    Mr Barclay says that Meridian has continued to build strong momentum to set the business up for future growth. This year, the company expects to commit over $1 billion of capital to new development projects.

    “The relatively fast decline in gas resources has put even greater emphasis on the need to deploy new renewable developments as quickly as possible, and also get more out of our existing fleet of hydro and wind generation. In that regard, we’ve had a few wins recently. We’ve reinstated capacity in the generation fleet after resolving transformer issues at Manapōuri and West Wind, and we’ve begun commissioning our Ruakākā grid scale battery. We’ve also made great progress in advancing a development pipeline that will deliver additional megawatts for many years to come,” says Neal Barclay.

    Meridian recently announced:

    A finalised consent for its 120MW Ruakākā solar development (February)
    Consent for its 90MW Mt Munro Wind Farm near Eketāhuna (February)
    A Scheme Implementation Agreement as part of its bid to acquire the remaining shares in NZ Windfarms (February)
    A Power Purchase Agreement with Harmony Energy / First Renewables in respect of their joint venture to build the 150MW Tauhei Solar Farm in the Waikato (January)
    A 50-50 joint venture with Nova Energy to build the 400MW Te Rahui solar farm at Rangitāiki near Taupō (December).

    The first half of FY25 has also seen tremendous progress in Meridian’s Retail business. Having completed a strategic reset and restructure to enable the business to meet changing technology and consumer needs, the company has launched three new products (Smart Hot Water, Smart EV Charging and the Four Hours Free Plan), with more to come over the remainder of the financial year.

    “Customers are responding to these changes, with record numbers signing up. As of 1 January, we had achieved our highest ever market share of electricity connections, with 16.58% across the Meridian and Powershop brands. Our brands also led the industry rankings for new connections in December, with Powershop first and Meridian second, and more than 4,000 connections that month across both brands,” says Neal Barclay.

    “The business has weathered an extraordinarily difficult set of circumstances and leveraged our financial strength to ensure the lights stayed on for New Zealand homes and businesses. At the same time, we’ve not backed away from our strategic goals and our customer market share has continued to grow as has our renewable development pipeline.”

    MIL OSI New Zealand News

  • MIL-OSI: Skyward Specialty Insurance Group Reports Fourth Quarter 2024 Results

    Source: GlobeNewswire (MIL-OSI)

    HOUSTON, Feb. 25, 2025 (GLOBE NEWSWIRE) — Skyward Specialty Insurance Group, Inc. (Nasdaq: SKWD) (“Skyward Specialty” or the “Company”) today reported fourth quarter 2024 net income of $14.4 million, or $0.35 per diluted share, compared to $29.3 million, or $0.74 per diluted share, for the same 2023 period. Net income for the year ended 2024 was $118.8 million, or $2.87 per diluted share, compared to $86.0 million, or $2.24 per diluted share, for the same 2023 period.

    Adjusted operating income(1) for the fourth quarter of 2024 was $33.2 million, or $0.80 per diluted share, compared to $24.3 million, or $0.61 per diluted share, for the same 2023 period. Adjusted operating income(1) for the year ended 2024 was $126.7 million, or $3.06 per diluted share, compared to $80.8 million, or $2.11 per diluted share, for the same 2023 period.

    Highlights for the fourth quarter included:

    • Gross written premiums of $388.4 million, an increase of $66.8 million, or 20.8%, when compared to 2023;
    • Adjusted combined ratio(1) of 91.6%, including catastrophe losses of 2.2 points;
    • Return on equity of 16.3% for the year ended 2024 compared to 15.9% for the same 2023 period;
    • Adjusted return on equity(1) of 17.4% for the year ended 2024 compared to 14.9% for the same 2023 period; and,
    • Book value per share of $19.79, an increase of 18% compared to December 31, 2023.
    (1) See “Reconciliation of Non-GAAP Financial Measures”

    Skyward Specialty Chairman and CEO Andrew Robinson commented, “We wrapped up another remarkable year for Skyward Specialty, delivering both outstanding underwriting results while growing gross written premiums at over 20% for the quarter and 19% for the full year, with six out of eight divisions growing double-digits over the prior year. Our 16.3% return on equity for the year was again an excellent outcome. Throughout 2024 we continued to thoughtfully diversify our product portfolio, strategically launching new units including Media Liability, Life Sciences, Mortgage and Credit, and Renewable Energy. Our focus and disciplined execution of our “Rule Our Niche” strategy, and the extraordinary efforts of my 600 plus colleagues made 2024 another impressive year for our Company, and we are confident that we have built the foundation that will propel us in 2025 and beyond.”

    Results of Operations

    Underwriting Results

    Premiums                        
    ($ in thousands)   Three months ended December 31,   Twelve months ended December 31,
    unaudited    2024     2023    %
    Change
       2024     2023    %
    Change
    Gross written premiums   $ 388,355     $ 321,605     20.8 %   $ 1,743,232     $ 1,459,829     19.4 %
    Ceded written premiums   $ (117,328 )   $ (107,488 )   9.2 %   $ (619,654 )   $ (549,138 )   12.8 %
    Net retention     69.8 %     66.6 %   NM(1)     64.5 %     62.4 %   NM(1)
    Net written premiums   $ 271,027     $ 214,117     26.6 %   $ 1,123,578     $ 910,691     23.4 %
    Net earned premiums   $ 293,240     $ 224,932     30.4 %   $ 1,056,722     $ 829,143     27.4 %
    (1)Not meaningful                        
                             

    The increase in gross written premiums for the fourth quarter and year ended 2024, when compared to the same 2023 periods, was driven by double-digit premium growth primarily from our surety, programs, captives, global property & agriculture and transactional E&S underwriting divisions.

    Combined Ratio   Three months ended
    December 31,
      Twelve months ended
    December 31,
    (unaudited)   2024    2023    2024    2023 
    Non-cat loss and LAE   60.5 %   60.9 %   60.6 %   60.9 %
    Cat loss and LAE(1)   2.2 %   0.4 %   1.7 %   1.4 %
    Prior accident year development – LPT(2)   4.2 %   (0.2 )%   1.1 %   (0.2 )%
    Loss Ratio   66.9 %   61.1 %   63.4 %   62.1 %
    Net policy acquisition costs   15.3 %   13.4 %   14.2 %   13.0 %
    Other operating and general expenses   13.9 %   16.3 %   15.3 %   16.3 %
    Commission and fee income   (0.3 )%   (0.1 )%   (0.6 )%   (0.7 )%
    Expense ratio   28.9 %   29.6 %   28.9 %   28.6 %
    Combined ratio   95.8 %   90.7 %   92.3 %   90.7 %
    Ex-Cat Combined Ratio(3)   93.6 %   90.3 %   90.6 %   89.3 %
                     
    Adjusted Underwriting Ratios                
    Adjusted loss ratio(2)   62.7 %   61.3 %   62.3 %   62.3 %
    Expense ratio   28.9 %   29.6 %   28.9 %   28.6 %
    Adjusted combined ratio(2)   91.6 %   90.9 %   91.2 %   90.9 %
    (1)Current accident year
    (2)See “Reconciliation of Non-GAAP Financial Measures”
    (3)Defined as the combined ratio excluding cat loss and LAE(1)            
                     

    The loss ratios for the fourth quarter and year ended 2024 increased 5.8 points and 1.3 points, respectively, when compared to the same 2023 periods, primarily due to the net impact of prior accident year development related to the LPT. The fourth quarter and year ended 2024 were also impacted by higher catastrophe losses, primarily from Hurricane Milton in the fourth quarter of 2024 and Hurricanes Helene and Beryl in the third quarter of 2024. The improvement in the non-cat loss and LAE ratios for the fourth quarter and year ended 2024, when compared to the same 2023 periods, was driven by the business mix shift.

    The expense ratio for the fourth quarter improved when compared to the same 2023 period primarily due to earnings leverage partially offset by the business mix shift. The expense ratio for the year ended 2024 increased slightly when compared to the same 2023 period, driven by the business mix shift.

    The expense ratios for all periods presented exclude the impact of IPO related stock compensation and secondary offering expenses, which are reported in other expenses in our condensed consolidated statements of operations and comprehensive income.

    Investment Results

    Net Investment Income                
    $ in thousands   Three months ended
    December 31,
      Twelve months ended
    December 31,
    (unaudited)    2024     2023     2024     2023 
    Short-term investments & cash and cash equivalents   $ 3,998     $ 3,670     $ 17,643     $ 11,677  
    Fixed income     15,909       11,680       57,631       36,547  
    Equities     771       880       2,745       2,212  
    Alternative & strategic investments     52       (2,226 )     2,667       (10,114 )
    Net investment income   $ 20,730     $ 14,004     $ 80,686     $ 40,322  
    Net unrealized (losses) gains on securities still held   $ (7,688 )   $ 8,736     $ 7,921     $ 11,130  
    Net realized losses     (2,721 )     (992 )     (1,665 )     (58 )
    Net investment (losses) gains   $ (10,409 )   $ 7,744     $ 6,256     $ 11,072  
     

    Beginning January 1, 2024 we simplified the investment portfolio classifications to align with our strategy and the underlying risk characteristics of the portfolio. The prior period has been reclassified to conform to the current period presentation.

    Net investment income for the fourth quarter and year ended 2024 increased $6.7 million and $40.4 million, respectively when compared to the same 2023 periods, primarily driven by (i) increased income from our fixed income portfolio and short-term investments due to higher yields and larger asset bases, and (ii) income from alternative and strategic investments compared to losses for the same 2023 periods, which were impacted by the decline in the fair value of limited partnership investments.

    Stockholders’ Equity

    Stockholders’ equity was $794.0 million at December 31, 2024 which represented a decrease of 0.4% when compared to stockholders’ equity of $797.5 million at September 30, 2024. The decrease in stockholders’ equity was primarily due to a decline in the market value of our investment portfolio partially offset by net income.

    Conference Call

    At 9:30 a.m. eastern time tomorrow, February 26, 2025, Skyward Specialty management will hold a conference call to discuss quarterly results with insurance industry analysts. Interested parties may listen to the discussion at investors.skywardinsurance.com under Events & Presentations. Additionally, investors can access the earnings call via conference call by registering via the conference link. Users will receive dial-in information and a unique PIN to join the call upon registering.

    Non-GAAP Financial Measures

    This release contains certain financial measures and ratios that are not required by, or presented in accordance with, generally accepted accounting principles in the United States (“GAAP”). We refer to these measures as “non-GAAP financial measures.” We use these non-GAAP financial measures when planning, monitoring, and evaluating our performance.

    We have chosen to exclude the net impact of the Loss Portfolio Transfer (“LPT”), all development on reserves fully or partially covered by the LPT and amortization of deferred gains associated with recoveries of prior LPT reserve strengthening in certain non-GAAP metrics, where noted, as the business subject to the LPT is not representative of our continuing business strategy. The business subject to the LPT is primarily related to policy years 2017 and prior, was generated and managed under prior leadership, and has either been exited or substantially repositioned during the reevaluation of our portfolio. The LPT was commuted effective January 31, 2025. We consider these non-GAAP financial measures to be useful metrics for our management and investors to facilitate operating performance comparisons from period to period. While we believe that these non-GAAP financial measures are useful in evaluating our business, this information should be considered supplemental in nature and is not meant to be a substitute for revenue or net income, in each case as recognized in accordance with GAAP. In addition, other companies, including companies in our industry, may calculate such measures differently, which reduces their usefulness as comparative measures. For more information regarding these non-GAAP financial measures and a reconciliation of such measures to comparable GAAP financial measures, see the section entitled “Reconciliation of Non-GAAP Financial Measures.”

    About Skyward Specialty Insurance Group, Inc.

    Skyward Specialty is a rapidly growing and innovative specialty insurance company, delivering commercial property and casualty products and solutions on a non-admitted and admitted basis. The Company operates through eight underwriting divisions – Accident & Health, Captives, Global Property & Agriculture, Industry Solutions, Professional Lines, Programs, Surety and Transactional E&S. SKWD stock is traded on the Nasdaq Global Select Market, which represents the top fourth of all Nasdaq listed companies.

    Skyward Specialty’s subsidiary insurance companies consist of Houston Specialty Insurance Company, Imperium Insurance Company, Great Midwest Insurance Company, and Oklahoma Specialty Insurance Company. These insurance companies are rated A (Excellent) with stable outlook by A.M. Best Company. Additional information about Skyward Specialty can be found on our website at www.skywardinsurance.com

    Forward-Looking Statements

    Except for historical information, all other information in this news release consists of forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995. The forward-looking statements are typically, but not always, identified through use of the words “believe,” “expect,” “enable,” “may,” “will,” “could,” “intends,” “estimate,” “anticipate,” “plan,” “predict,” “probable,” “potential,” “possible,” “should,” “continue,” and other words of similar meaning. These forward-looking statements are subject to risks and uncertainties that could cause actual results to differ materially from those projected, anticipated or implied. The most significant of these uncertainties are described in Skyward Specialty’s Form 10-K, and include (but are not limited to) legislative changes at both the state and federal level, state and federal regulatory rule making promulgations and adjudications, class action litigation involving the insurance industry and judicial decisions affecting claims, policy coverages and the general costs of doing business, the potential loss of key members of our management team or key employees and our ability to attract and retain personnel, the impact of competition on products and pricing, inflation in the costs of the products and services insurance pays for, product development, geographic spread of risk, weather and weather-related events, other types of catastrophic events, our ability to obtain reinsurance coverage at prices and on terms that allow us to transfer risk and adequately protect our company against financial loss, and losses resulting from reinsurance counterparties failing to pay us on reinsurance claims. These forward-looking statements speak only as of the date of this release and the Company does not undertake any obligation to update or revise any forward-looking information to reflect changes in assumptions, the occurrence of unanticipated events, or otherwise.

    Skyward Specialty Insurance Group, Inc.

    Investor contact:
    Natalie Schoolcraft,
    nschoolcraft@skywardinsurance.com 
    614-494-4988

    or

    Media contact:
    Haley Doughty
    hdoughty@skywardinsurance.com 
    713-935-4944

    Consolidated Balance Sheets        
    ($ in thousands, except share and per share amounts)        
    (unaudited)   December 31,
    2024
      December 31,
    2023
    Assets        
    Investments:        
    Fixed maturity securities, available-for-sale, at fair value (amortized cost of $1,320,266 and $1,047,713, respectively)   $ 1,292,218     $ 1,017,651  
    Fixed maturity securities, held-to-maturity, at amortized cost (net of allowance for credit losses of $243 and $329, respectively)     39,153       42,986  
    Equity securities, at fair value     106,254       118,249  
    Mortgage loans, at fair value     26,490       50,070  
    Equity method investments     98,594       110,653  
    Other long-term investments     33,182       3,852  
    Short-term investments, at fair value     274,929       270,226  
    Total investments     1,870,820       1,613,687  
    Cash and cash equivalents     121,603       65,891  
    Restricted cash     35,922       34,445  
    Premiums receivable, net     321,641       179,235  
    Reinsurance recoverables, net     857,876       596,334  
    Ceded unearned premium     203,901       186,121  
    Deferred policy acquisition costs     113,183       91,955  
    Deferred income taxes     30,486       21,991  
    Goodwill and intangible assets, net     87,348       88,435  
    Other assets     86,698       75,341  
    Total assets   $ 3,729,478     $ 2,953,435  
    Liabilities and stockholders’ equity        
    Liabilities:        
    Reserves for losses and loss adjustment expenses   $ 1,782,383     $ 1,314,501  
    Unearned premiums     637,185       552,532  
    Deferred ceding commission     40,434       37,057  
    Reinsurance and premium payables     177,070       150,156  
    Funds held for others     102,665       58,588  
    Accounts payable and accrued liabilities     76,206       50,880  
    Notes payable     100,000       50,000  
    Subordinated debt, net of debt issuance costs     19,536       78,690  
    Total liabilities     2,935,479       2,292,404  
    Stockholders’ equity        
    Common stock, $0.01 par value, 500,000,000 shares authorized, 40,127,908 and 39,863,756 shares issued and outstanding, respectively     401       399  
    Additional paid-in capital     718,598       710,855  
    Stock notes receivable           (5,562 )
    Accumulated other comprehensive loss     (22,120 )     (22,953 )
    Retained earnings (accumulated deficit)     97,120       (21,708 )
    Total stockholders’ equity     793,999       661,031  
    Total liabilities and stockholders’ equity   $ 3,729,478     $ 2,953,435  
             
    Condensed Consolidated Statements of Operations and Comprehensive Income
    ($ in thousands)   Three months ended
    December 31,
      Twelve months ended
    December 31,
    (unaudited)    2024     2023     2024     2023 
                     
    Revenues:                
    Net earned premiums   $ 293,240     $ 224,932     $ 1,056,722     $ 829,143  
    Commission and fee income     806       247       6,703       6,064  
    Net investment income     20,730       14,004       80,686       40,322  
    Net investment (losses) gains     (10,409 )     7,744       6,256       11,072  
    Other income (loss)     35       (632 )     (167 )     (632 )
    Total revenues     304,402       246,295       1,150,200       885,969  
    Expenses:                
    Losses and loss adjustment expenses     196,320       137,396       669,809       515,237  
    Underwriting, acquisition and insurance expenses     85,487       66,791       311,757       243,444  
    Interest expense     2,091       2,774       9,496       10,024  
    Amortization expense     908       462       2,007       1,798  
    Other expenses     1,042       1,303       4,392       5,364  
    Total expenses     285,848       208,726       997,461       775,867  
    Income before income taxes     18,554       37,569       152,739       110,102  
    Income tax expense     4,148       8,304       33,911       24,118  
    Net income     14,406       29,265       118,828       85,984  
    Net income attributable to participating securities                       1,677  
    Net income attributable to common stockholders   $ 14,406     $ 29,265     $ 118,828     $ 84,307  
    Comprehensive income:                
    Net income   $ 14,406     $ 29,265     $ 118,828     $ 85,984  
    Other comprehensive income:                
    Unrealized gains and losses on investments:                
    Net change in unrealized (losses) gains on investments, net of tax     (14,735 )     30,825       9,792       25,516  
    Reclassification adjustment for losses on securities no longer held, net of tax     (5,682 )     (105 )     (8,959 )     (4,984 )
    Total other comprehensive (loss) income     (20,417 )     30,720       833       20,532  
    Comprehensive (loss) income   $ (6,011 )   $ 59,985     $ 119,661     $ 106,516  
                     
    Share and Per Share Data                
    ($ in thousands, except share and per share amounts)   Three months ended
    December 31,
      Twelve months ended
    December 31,
    (unaudited)   2024   2023   2024   2023
                     
    Weighted average basic shares     40,107,617       37,570,274       40,056,475       36,031,907  
    Weighted average diluted shares     41,622,397       39,582,352       41,377,460       38,317,534  
                     
    Basic earnings per share   $ 0.36     $ 0.78     $ 2.97     $ 2.34  
    Diluted earnings per share   $ 0.35     $ 0.74     $ 2.87     $ 2.24  
    Basic adjusted operating earnings per share   $ 0.83     $ 0.65     $ 3.16     $ 2.20  
    Diluted adjusted operating earnings per share   $ 0.80     $ 0.61     $ 3.06     $ 2.11  
                     
    Annualized ROE (1)     7.2 %     19.6 %     16.3 %     15.9 %
    Annualized adjusted ROE (2)     16.7 %     16.3 %     17.4 %     14.9 %
    Annualized ROTE (3)     8.1 %     23.0 %     18.6 %     19.0 %
    Annualized adjusted ROTE (4)     18.8 %     19.1 %     19.8 %     17.9 %
                     
                December 31   December 31
                 2024     2023 
                     
    Shares outstanding             40,127,908       39,863,756  
    Fully diluted shares outstanding             42,059,182       41,771,854  
                     
    Book value per share           $ 19.79     $ 16.72  
    Fully diluted book value per share           $ 18.88     $ 15.96  
    Fully diluted tangible book value per share           $ 16.80     $ 13.84  
                     
    (1)Annualized ROE is net income expressed on an annualized basis as a percentage of average beginning and ending stockholders’ equity during the period
    (2)Annualized adjusted ROE is adjusted operating income expressed on an annualized basis as a percentage of average beginning and ending stockholders’ equity during the period
    (3)Annualized ROTE is net income expressed on an annualized basis as a percentage of average beginning and ending tangible stockholders’ equity during the period
    (4)Annualized adjusted ROTE is adjusted operating income expressed on an annualized basis as a percentage of average beginning and ending tangible stockholders’ equity during the period

    Adjusted operating income – We define adjusted operating income as net income excluding the impact of certain items that may not be indicative of underlying business trends, operating results, or future outlook, net of tax impact. We use adjusted operating income as an internal performance measure in the management of our operations because we believe it gives our management and other users of our financial information useful insight into our results of operations and our underlying business performance. Adjusted operating income should not be viewed as a substitute for net income calculated in accordance with GAAP, and other companies may define adjusted operating income differently.        

    ($ in thousands) Three months ended December 31,   Twelve months ended December 31,
    (unaudited)  2024    2023     2024    2023 
      Pre-tax   After-tax   Pre-tax   After-tax   Pre-tax   After-tax   Pre-tax   After-tax
    Income as reported $ 18,554     $ 14,406     $ 37,569     $ 29,265     $ 152,739     $ 118,828     $ 110,102     $ 85,984  
    Less (add):                              
    Net investment (losses) gains   (10,409 )     (8,223 )     7,744       6,118       6,256       4,942       11,072       8,747  
    Net impact of loss portfolio transfer   (12,398 )     (9,794 )     457       361       (11,598 )     (9,162 )     1,427       1,127  
    Other loss   35       28       (632 )     (499 )     (167 )     (132 )     (632 )     (499 )
    Other expenses   (1,042 )     (823 )     (1,303 )     (1,029 )     (4,392 )     (3,470 )     (5,364 )     (4,238 )
    Adjusted operating income $ 42,368     $ 33,218     $ 31,303     $ 24,314     $ 162,640     $ 126,650     $ 103,599     $ 80,847  
                                   

    Underwriting income – We define underwriting income as net income before income taxes excluding net investment income, net realized and unrealized gains and losses on investments, impairment charges, interest expense, amortization expense and other income and expenses. Underwriting income represents the pre-tax profitability of our underwriting operations and allows us to evaluate our underwriting performance without regard to investment income. We use this metric as we believe it gives our management and other users of our financial information useful insight into our underlying business performance. Underwriting income should not be viewed as a substitute for pre-tax income calculated in accordance with GAAP, and other companies may define underwriting income differently.

    ($ in thousands)   Three months ended
    December 31,
      Twelve months ended
    December 31,
    (unaudited)    2024     2023     2024     2023 
    Income before income taxes   $ 18,554     $ 37,569     $ 152,739     $ 110,102  
    Add:                
    Interest expense     2,091       2,774       9,496       10,024  
    Amortization expense     908       462       2,007       1,798  
    Other expenses     1,042       1,303       4,392       5,364  
    Less (add):                
    Net investment income     20,730       14,004       80,686       40,322  
    Net investment (losses) gains     (10,409 )     7,744       6,256       11,072  
    Other income (loss)     35       (632 )     (167 )     (632 )
    Underwriting income   $ 12,239     $ 20,992     $ 81,859     $ 76,526  
                     

    Adjusted Loss Ratio / Adjusted Combined Ratio – We define adjusted loss ratio and adjusted combined ratio as the corresponding ratio (calculated in accordance with GAAP), excluding losses and LAE related to the LPT and all development on reserves fully or partially covered by the LPT and amortization of deferred gains associated with recoveries of prior LPT reserve strengthening. We use these adjusted ratios as internal performance measures in the management of our operations because we believe they give our management and other users of our financial information useful insight into our results of operations and our underlying business performance. Our adjusted loss ratio and adjusted combined ratio should not be viewed as substitutes for our loss ratio and combined ratio, respectively.

    ($ in thousands)   Three months ended
    December 31,
      Twelve months ended
    December 31,
    (unaudited)   2024   2023   2024   2023
    Net earned premiums   $ 293,240     $ 224,932     $ 1,056,722     $ 829,143  
                     
    Losses and LAE     196,320       137,396       669,809       515,237  
    Less: Pre-tax net impact of LPT     12,398       (457 )     11,598       (1,427 )
    Adjusted losses and LAE   $ 183,922     $ 137,853     $ 658,211     $ 516,664  
                     
    Loss ratio     66.9 %     61.1 %     63.4 %     62.1 %
    Less: net impact of LPT     4.2 %     (0.2 )%     1.1 %     (0.2 )%
    Adjusted loss ratio     62.7 %     61.3 %     62.3 %     62.3 %
                     
    Combined ratio     95.8 %     90.7 %     92.3 %     90.7 %
    Less: net impact of LPT     4.2 %     (0.2 )%     1.1 %     (0.2 )%
    Adjusted combined ratio     91.6 %     90.9 %     91.2 %     90.9 %
                     

    Tangible Stockholders’ Equity – We define tangible stockholders’ equity as stockholders’ equity less goodwill and intangible assets. Our definition of tangible stockholders’ equity may not be comparable to that of other companies and should not be viewed as a substitute for stockholders’ equity calculated in accordance with GAAP. We use tangible stockholders’ equity internally to evaluate the strength of our balance sheet and to compare returns relative to this measure.

    ($ in thousands)   December 31,
    (unaudited)    2024    2023
    Stockholders’ equity   $         793,999   $         661,031
    Less: Goodwill and intangible assets             87,348             88,435
    Tangible stockholders’ equity   $         706,651   $         572,596
             
        Three months ended December 31,   Twelve months ended December 31,
    ($ in thousands)   2024   2023   %
    Change
      2024   2023   % Change
    Industry Solutions     80,738     78,796   2.5 %     317,198     305,476   3.8 %
    Global Property & Agriculture   $ 31,681   $ 25,996   21.9 %   $ 311,402   $ 273,191   14.0 %
    Captives     57,765     40,375   43.1 %     241,902     167,624   44.3 %
    Programs     52,151     35,694   46.1 %     218,407     178,726   22.2 %
    Accident & Health     44,594     38,882   14.7 %     173,073     151,701   14.1 %
    Transactional E&S     36,262     31,560   14.9 %     169,053     122,508   38.0 %
    Professional Lines     39,130     40,145   (2.5 )%     159,785     154,565   3.4 %
    Surety     46,034     30,157   52.6 %     152,429     106,056   43.7 %
    Total gross written premiums(1)   $ 388,355   $ 321,605   20.8 %   $ 1,743,249   $ 1,459,847   19.4 %
    (1)Excludes exited business                        

    The MIL Network

  • MIL-OSI: Sprout Social Announces Fourth Quarter 2024 Financial Results

    Source: GlobeNewswire (MIL-OSI)

    CHICAGO, Feb. 25, 2025 (GLOBE NEWSWIRE) — Sprout Social, Inc. (“Sprout Social”, the “Company”) (Nasdaq: SPT), an industry-leading provider of cloud-based social media management software, today announced financial results for its fourth quarter ended December 31, 2024.

    “The Sprout team delivered a solid fourth quarter, driving 14% revenue growth and 26% growth in cRPO, laying the foundation for future growth in 2025 and beyond. As we work to define the future of social media management, we remain focused on execution—winning the enterprise, driving customer health, expanding our partnership ecosystem, and driving deeper engagement in our customer base,” said Ryan Barretto, CEO.

    Fourth Quarter 2024 Financial Highlights

    Revenue

    • Revenue was $107.1 million, up 14% compared to the fourth quarter of 2023.
    • Total remaining performance obligations (RPO) of $351.5 million as of December 31, 2024, up 28% year-over-year.
    • Current remaining performance obligations (cRPO) of $249.4 million as of December 31, 2024, up 26% year-over-year.

    Operating Income (Loss)

    • GAAP operating loss was ($13.7) million, compared to ($18.2) million in the fourth quarter of 2023.
    • Non-GAAP operating income was $11.4 million, compared to $1.7 million in the fourth quarter of 2023.

    Net Loss

    • GAAP net loss was ($14.4) million, compared to ($20.1) million in the fourth quarter of 2023.
    • Non-GAAP net income was $10.7 million, compared to $1.0 million in the fourth quarter of 2023.
    • GAAP net loss per share was ($0.25) based on 57.5 million weighted-average shares of common stock outstanding, compared to ($0.36) based on 56.1 million weighted-average shares of common stock outstanding in the fourth quarter of 2023.
    • Non-GAAP net income per share was $0.19 based on 57.5 million weighted-average shares of common stock outstanding, compared to $0.02 based on 56.1 million weighted-average shares of common stock outstanding in the fourth quarter of 2023.

    Cash

    • Cash and equivalents and marketable securities totaled $90.2 million as of December 31, 2024, compared to $91.5 million as of September 30, 2024.
    • Net cash provided by (used in) operating activities was $4.1 million, compared to ($2.6) million in the fourth quarter of 2023.
    • Non-GAAP free cash flow was $6.6 million, compared to ($0.3) million in the fourth quarter of 2023.

    See “Use of Non-GAAP Financial Measures” below for definitions of Non-GAAP operating income (loss), Non-GAAP net income (loss), Non-GAAP net income (loss) per share and non-GAAP free cash flow and the financial tables that accompany this release for reconciliations of our non-GAAP measures to their closest comparable GAAP measures. See “Key Business Metrics” below for how Sprout Social defines RPO, cRPO, the number of customers contributing over $10,000 in ARR, the number of customers contributing over $50,000 in ARR, dollar-based net retention rate and dollar-based net retention rate excluding small-and-medium-sized business customers.

    Customer Metrics

    • Grew number of customers contributing over $10,000 in ARR to 9,327 customers as of December 31, 2024, up 7% compared to December 31, 2023.
    • Grew number of customers contributing over $50,000 in ARR to 1,718 customers as of December 31, 2024, up 23% compared to December 31, 2023.
    • Dollar-based net retention rate was 104% in 2024, compared to 107% in 2023.
    • Dollar-based net retention rate excluding small-and-medium-sized business (SMB) customers was 108% in 2024, compared to 111% in 2023.

    Recent Customer Highlights

    • During the fourth quarter, we had the opportunity to grow with new and existing customers like: Under Armour, ESPN, Rocket Mortgage, Klaviyo, Carhartt, Campbell, and Cushman & Wakefield.

    Recent Business Highlights

    Sprout Social recently:

    • Released a new Total Economic Impact™ study conducted by Forrester Consulting that found Sprout Social enabled customers to achieve a 268% return on investment (link)
    • Recognized by G2’s Best Software Awards as a top company across seven categories (link)
    • Announced rebranded influencer marketing platform to prepare brands for the next generation of social (link)
    • Launched the 2025 Sprout Social Index™ highlighting the latest trends in social culture and brand implications for the future (link)
    • Unveiled updates to its suite of AI solutions that enable marketers to unlock new potential and boost competitiveness (link)
    • Named a leader in worldwide social media marketing software for large enterprises by IDC Marketscape (link) and earned a 2025 Buyer’s Choice Award from TrustRadius (link)
    • Recognized by Built In as a Best Place to Work for the sixth consecutive year (link)

    First Quarter and 2025 Financial Outlook

    For the first quarter of 2025, the Company currently expects:

    • Total revenue between $107.2 million and $108.0 million.
    • Non-GAAP operating income between $8.5 million and $9.5 million.
    • Non-GAAP net income per share between $0.14 and $0.16 based on approximately 58.5 million weighted-average shares of common stock outstanding.

    For the full year 2025, the Company currently expects:

    • Total revenue between $448.1 million and $453.1 million.
    • Non-GAAP operating income between $38.2 million and $43.2 million.
    • Non-GAAP net income per share between $0.65 and $0.74 based on approximately 59.3 million weighted-average shares of common stock outstanding.

    The Company’s first quarter and 2025 financial outlook is based on a number of assumptions that are subject to change and many of which are outside the Company’s control. If actual results vary from these assumptions, the Company’s expectations may change. There can be no assurance that the Company will achieve these results.

    The Company does not provide guidance for operating loss, the most directly comparable GAAP measure to non-GAAP operating income, or net loss per share, the most directly comparable GAAP measure to non-GAAP net income per share, and similarly cannot provide a reconciliation between its forecasted non-GAAP operating income and non-GAAP net income per share and these comparable GAAP measures without unreasonable effort due to the unavailability of reliable estimates for certain items. These items are not within the Company’s control and may vary greatly between periods and could significantly impact future financial results.

    Conference Call Information

    The financial results and business highlights will be discussed on a conference call and webcast scheduled at 4:00 p.m. Central Time (5:00 p.m. Eastern Time) today, February 25, 2025. Online registration for this event conference call can be found at https://registrations.events/direct/Q4I1913111787. The live webcast of the conference call can be accessed from Sprout Social’s investor relations website at http://investors.sproutsocial.com.

    Following completion of the events, a webcast replay will also be available at http://investors.sproutsocial.com for 12 months.

    About Sprout Social
    Sprout Social is a global leader in social media management and analytics software. Sprout’s unified platform puts powerful social data into the hands of approximately 30,000 brands so they can make strategic decisions that drive business growth and innovation. With a full suite of social media management solutions, Sprout offers comprehensive publishing and engagement functionality, customer care, connected workflows and AI-powered business intelligence. Sprout’s award-winning software operates across all major social media networks and digital platforms. For more information about Sprout Social (NASDAQ: SPT), visit sproutsocial.com.

    Forward-Looking Statements

    This press release contains “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. In some cases, you can identify forward-looking statements by terms such as “anticipate,” “believe,” “can,” “continue,” “could,” “estimate,” “expect,” “explore,””future,” “intend,” “long-term model,” “may,” “medium to longer term goals,” “might” “outlook,” “plan,” “potential,” “predict,” “project,” “should,” “strategy,” “target,” “will,” “would,” or the negative of these terms, and similar expressions intended to identify forward-looking statements. However, not all forward-looking statements contain these identifying words. These statements may relate to our market size and growth strategy, our estimated and projected costs, margins, revenue, expenditures and customer and financial growth rates, our Q1 2025 and full year 2025 financial outlook, our plans and objectives for future operations, growth, initiatives or strategies. By their nature, these statements are subject to numerous uncertainties and risks, including factors beyond our control, that could cause actual results, performance or achievement to differ materially and adversely from those anticipated or implied in the forward-looking statements. These assumptions, uncertainties and risks include that, among others: we may not be able to sustain our revenue and customer growth rate in the future, including due to risks associated with our strategic focus on enterprise customers; price increases have and may continue to negatively impact demand for our products, customer acquisition and retention and reduce the total number of customers or customer additions; our business would be harmed by any significant interruptions, delays or outages in services from our platform, our API providers, or certain social media platforms; if we are unable to attract potential customers through unpaid channels, convert this traffic to free trials or convert free trials to paid subscriptions, our business and results of operations may be adversely affected; we may be unable to successfully enter new markets, manage our international expansion and comply with any applicable international laws and regulations; we may be unable to integrate acquired businesses or technologies successfully or achieve the expected benefits of such acquisitions and investments; unstable market and economic conditions, such as recession risks, effects of inflation, labor shortages, supply chain issues, high interest rates, and the impacts of current and potential future bank failures and impacts of ongoing overseas conflicts, have and could continue to adversely impact our business and that of our existing and prospective customers, which may result in reduced demand for our products; we may not be able to generate sufficient cash to service our indebtedness; covenants in our credit agreement may restrict our operations, and if we do not effectively manage our business to comply with these covenants, our financial condition could be adversely impacted; any cybersecurity-related attack, significant data breach or disruption of the information technology systems or networks on which we rely could negatively affect our business; changing regulations relating to privacy, information security and data protection could increase our costs, affect or limit how we collect and use personal information and harm our brand; and risks related to ongoing legal proceedings. Additional risks and uncertainties that could cause actual outcomes and results to differ materially from those contemplated by the forward-looking statements are included under the caption “Risk Factors” and elsewhere in our filings with the Securities and Exchange Commission (the “SEC”), including our Annual Report on Form 10-K for the year ended December 31, 2023 filed with the SEC on February 23, 2024 and our Annual Report on Form 10-K for the year ended December 31, 2024, to be filed with the SEC as well as any future reports that we file with the SEC. Moreover, you should interpret many of the risks identified in those reports as being heightened as a result of the current instability in market and economic conditions. Forward-looking statements speak only as of the date the statements are made and are based on information available to Sprout Social at the time those statements are made and/or management’s good faith belief as of that time with respect to future events. Sprout Social assumes no obligation to update forward-looking statements to reflect events or circumstances after the date they were made, except as required by law.

    Use of Non-GAAP Financial Measures

    We have provided in this press release certain financial information that has not been prepared in accordance with generally accepted accounting principles in the United States (“GAAP”). Our management uses these non-GAAP financial measures internally in analyzing our financial results and believes that use of these non-GAAP financial measures is useful to investors as an additional tool to evaluate ongoing operating results and trends and in comparing our financial results with other companies in our industry, many of which present similar non-GAAP financial measures. Non-GAAP financial measures are not meant to be considered in isolation or as a substitute for comparable financial measures prepared in accordance with GAAP and should be read only in conjunction with our consolidated financial statements prepared in accordance with GAAP. A reconciliation of our historical non-GAAP financial measures to the most directly comparable GAAP measures has been provided in the financial statement tables included in this press release, and investors are encouraged to review these reconciliations.

    Non-GAAP gross profit. We define non-GAAP gross profit as GAAP gross profit, excluding stock-based compensation expense, amortization expense associated with the acquired developed technology from our acquisition of Tagger Media, Inc. (the “Tagger acquisition”) and restructuring charges. We believe non-GAAP gross profit provides our management and investors consistency and comparability with our past financial performance and facilitates period-to-period comparisons of operations, as it eliminates the effect of stock-based compensation, amortization expense and restructuring charges which are often unrelated to overall operating performance. During the fourth quarter of 2024, we revised our definition of non-GAAP gross profit to exclude restructuring charges associated with a workforce reorganization, consisting primarily of severance and other personnel-related costs.

    Non-GAAP gross margin. We define non-GAAP gross margin as non-GAAP gross profit as a percentage of revenue.

    Non-GAAP operating income (loss). We define non-GAAP operating income (loss) as GAAP loss from operations, excluding stock-based compensation expense, acquisition-related expenses and amortization expense associated with the acquired intangible assets from the Tagger acquisition, restructuring charges and non-cash gains from lease modifications. We believe non-GAAP operating income (loss) provides our management and investors consistency and comparability with our past financial performance and facilitates period-to-period comparisons of operations, as it eliminates the effect of stock-based compensation, acquisition-related expenses, amortization expense, restructuring charges and non-cash gains from lease modifications, which are often unrelated to overall operating performance. During the fourth quarter of 2024, we revised our definition of non-GAAP operating income (loss) to exclude restructuring charges associated with a workforce reorganization, consisting primarily of severance and other personnel-related costs, and non-cash gain related to an office lease modification.

    Non-GAAP operating margin. We define non-GAAP operating margin as non-GAAP operating income (loss) as a percentage of revenue.

    Non-GAAP net income (loss). We define non-GAAP net income (loss) as GAAP net loss, excluding stock-based compensation expense, acquisition-related expenses, amortization expense associated with the acquired intangible assets from the Tagger acquisition, tax expense due to changes in valuation allowances from business acquisitions, restructuring charges and non-cash gains from lease modifications. We believe non-GAAP net income (loss) provides our management and investors consistency and comparability with our past financial performance and facilitates period-to-period comparisons of operations, as this non-GAAP financial measure eliminates the effect of stock-based compensation, acquisition-related expenses, amortization expense and tax expense due to changes in valuation allowances from business acquisitions, restructuring charges and non-cash gains from lease modifications, which are often unrelated to overall operating performance. During the fourth quarter of 2024, we revised our definition of non-GAAP net income (loss) to exclude restructuring charges associated with a workforce reorganization, consisting primarily of severance and other personnel-related costs, and non-cash gain related to an office lease modification.

    Non-GAAP net income (loss) per share. We define non-GAAP net income (loss) per share as GAAP net loss per share attributable to common shareholders, basic and diluted, excluding stock-based compensation expense, acquisition-related expenses, amortization expense associated with the acquired intangible assets from the Tagger acquisition, tax expense due to changes in valuation allowances from business acquisitions, restructuring charges and non-cash gains from lease modifications. We believe non-GAAP net income (loss) per share provides our management and investors consistency and comparability with our past financial performance and facilitates period-to-period comparisons of operations, as this non-GAAP financial measure eliminates the effect of stock-based compensation, acquisition-related expenses, amortization expense, tax expense due to changes in valuation allowances from business acquisitions, restructuring charges and non-cash gains from lease modifications, which are often unrelated to overall operating performance. During the fourth quarter of 2024, we revised our definition of non-GAAP net income (loss) per share to exclude restructuring charges associated with a workforce reorganization, consisting primarily of severance and other personnel-related costs, and non-cash gain related to an office lease modification.

    Non-GAAP free cash flow. We define non-GAAP free cash flow as net cash provided by (used in) operating activities less expenditures for property and equipment, acquisition-related costs, interest and payments related to restructuring charges. Non-GAAP free cash flow does not reflect our future contractual obligations or represent the total increase or decrease in our cash balance for a given period. We believe non-GAAP free cash flow is a useful indicator of liquidity that provides information to management and investors about the amount of cash used in our core operations that, after expenditures for property and equipment, acquisition-related costs, interest and payments related to restructuring charges, is not available for strategic initiatives. During the fourth quarter of 2024, we revised our definition of non-GAAP free cash flow to exclude payments related to restructuring charges associated with a workforce reorganization.

    Non-GAAP free cash flow margin. We define non-GAAP free cash flow margin as non-GAAP free cash flow as a percentage of revenue.

    Non-GAAP sales and marketing expenses, non-GAAP research and development expenses and non-GAAP general and administrative expenses. Non-GAAP sales and marketing expenses, non-GAAP research and development expenses and non-GAAP general and administrative expenses are defined as sales and marketing expenses, research and development expenses and general and administrative expenses, respectively, less stock-based compensation expense, acquisition-related expenses, restructuring charges and non-cash gains from lease modifications. We believe these non-GAAP measures provide our management and investors with insight into day-to-day operating expenses given that these measures eliminate the effect of stock-based compensation, acquisition-related expenses, restructuring charges and non-cash gains from lease modifications. During the fourth quarter of 2024, we revised our definition of non-GAAP general and administrative expenses to exclude restructuring charges associated with a workforce reorganization, consisting primarily of severance and other personnel-related costs, and non-cash gain related to an office lease modification.

    Key Business Metrics

    Remaining performance obligations (“RPO”). RPO, or remaining performance obligations, represents contracted revenue that has not yet been recognized, and includes deferred revenue and amounts that will be invoiced and recognized in future periods.

    Current remaining performance obligations (“cRPO”). cRPO, or current RPO, represents contracted revenue that has not yet been recognized, and includes deferred revenue and amounts that will be invoiced and recognized in the next 12 months.

    Number of customers contributing more than $10,000 in ARR. We define number of customers contributing more than $10,000 in ARR as those on a paid subscription plan that had more than $10,000 in ARR as of a period end. We view the number of customers that contribute more than $10,000 in ARR as a measure of our ability to scale with our customers and attract larger organizations. We believe this represents potential for future growth, including expanding within our current customer base.

    Number of customers contributing more than $50,000 in ARR. We define number of customers contributing more than $50,000 in ARR as those on a paid subscription plan that had more than $50,000 in ARR as of a period end. We view the number of customers that contribute more than $50,000 in ARR as a measure of our ability to scale with large customers and attract sophisticated organizations. We believe this represents potential for future growth, including expanding within our current customer base.

    Dollar-based net retention rate. We calculate dollar-based net retention rate by dividing the ARR from our customers as of December 31st in the reported year by the ARR from those same customers as of December 31st in the previous year. This calculation is net of upsells, contraction, cancellation or expansion during the period but excludes ARR from new customers. We use dollar-based net retention to evaluate the long-term value of our customer relationships, because we believe this metric reflects our ability to retain and expand subscription revenue generated from our existing customers.

    Dollar-based net retention rate excluding SMB customers. We calculate dollar-based net retention rate excluding SMB customers by dividing the ARR from all customers excluding ARR from customers that we have identified or that self-identified as having less than 50 employees as of December 31st in the reported year by the ARR from those same customers as of December 31st of the previous year. This calculation is net of upsells, contraction, cancellation or expansion during the period but excludes ARR from new customers. We used dollar-based net retention excluding SMB customers to evaluate the long-term value of our larger customer relationships, because we believe this metric reflects our ability to retain and expand subscription revenue generated from our existing customers.

    While we no longer believe that ARR and number of customers are key performance indicators of Sprout Social’s business, these metrics are necessary for an understanding of how we define number of customers contributing over $10,000 in ARR and number of customers contributing over $50,000 in ARR. For this purpose, we define ARR as the annualized revenue run-rate of subscription agreements from all customers as of the last date of the specified period and we define a customer as a unique account, multiple accounts containing a common non-personal email domain, or multiple accounts governed by a single agreement or entity.

    Availability of Information on Sprout Social’s Website and Social Media Profiles

    Investors and others should note that Sprout Social routinely announces material information to investors and the marketplace using SEC filings, press releases, public conference calls, webcasts and the Sprout Social Investors website. We also intend to use the social media profiles listed below as a means of disclosing information about us to our customers, investors and the public. While not all of the information that the Company posts to the Sprout Social Investors website or to social media profiles is of a material nature, some information could be deemed to be material. Accordingly, the Company encourages investors, the media, and others interested in Sprout Social to review the information that it shares at the Investors link located at the bottom of the page on www.sproutsocial.com and to regularly follow our social media profiles. Users may automatically receive email alerts and other information about Sprout Social when enrolling an email address by visiting “Email Alerts” in the “Shareholder Services” section of Sprout Social’s Investor website at https://investors.sproutsocial.com/.

    Social Media Profiles:
    www.twitter.com/SproutSocial 
    www.twitter.com/SproutSocialIR 
    www.facebook.com/SproutSocialInc
    www.linkedin.com/company/sprout-social-inc-/
    www.instagram.com/sproutsocial

    Contact

    Media:
    Layla Revis
    Email: pr@sproutsocial.com
    Phone: (866) 878-3231

    Investors:
    Alex Kurtz
    Twitter: @SproutSocialIR
    Email: investors@sproutsocial.com
    Phone: (312) 528-9166

     
    Sprout Social, Inc.
    Consolidated Statements of Operations (Unaudited)
    (in thousands, except share and per share data)
           
      Three Months Ended December 31,
      2024    2023 
    Revenue      
    Subscription $ 105,922   $ 92,224
    Professional services and other 1,168   1,360
    Total revenue 107,090   93,584
    Cost of revenue(1)      
    Subscription 23,094   20,597
    Professional services and other 319   364
    Total cost of revenue 23,413   20,961
    Gross profit 83,677   72,623
    Operating expenses      
    Research and development(1) 27,627   22,661
    Sales and marketing(1) 45,889   47,380
    General and administrative(1) 23,838   20,805
    Total operating expenses 97,354   90,846
    Loss from operations (13,677)   (18,223)
    Interest expense (656)   (1,544)
    Interest income 878   1,210
    Other expense, net (620)   (118)
    Loss before income taxes (14,075)   (18,675)
    Income tax expense 342   1,402
    Net loss $ (14,417)   $ (20,077)
    Net loss per share attributable to common shareholders, basic and diluted $ (0.25)   $ (0.36)
    Weighted-average shares outstanding used to compute net loss per share, basic and diluted 57,511,942   56,098,243
           
    (1) Includes stock-based compensation expense as follows:      
       
      Three Months Ended December 31,
      2024    2023 
    Cost of revenue $ 1,046   $ 895
    Research and development 6,640   5,529
    Sales and marketing 7,017   7,770
    General and administrative 7,750   4,465
    Total stock-based compensation expense $ 22,453   $ 18,659
    Sprout Social, Inc.
    Consolidated Statements of Operations (Unaudited)
    (in thousands, except share and per share data)
           
      Twelve Months Ended December 31,
      2024   2023
    Revenue      
    Subscription $ 402,022   $ 330,458
    Professional services and other 3,886   3,185
    Total revenue 405,908   333,643
    Cost of revenue(1)      
    Subscription 90,305   75,076
    Professional services and other 1,170   1,192
    Total cost of revenue 91,475   76,268
    Gross profit 314,433   257,375
    Operating expenses      
    Research and development(1) 102,794   79,550
    Sales and marketing(1) 184,122   168,091
    General and administrative(1) 87,873   79,011
    Total operating expenses 374,789   326,652
    Loss from operations (60,356)   (69,277)
    Interest expense (3,525)   (2,754)
    Interest income 3,973   7,021
    Other expense, net (1,393)   (768)
    Loss before income taxes (61,301)   (65,778)
    Income tax expense 670   649
    Net loss $ (61,971)   $ (66,427)
    Net loss per share attributable to common shareholders, basic and diluted $ (1.09)   $ (1.19)
    Weighted-average shares outstanding used to compute net loss per share, basic and diluted 56,935,910   55,664,404
           
    (1) Includes stock-based compensation expense as follows:      
       
      Twelve Months Ended December 31,
      2024   2023
    Cost of revenue $ 3,936   $ 3,224
    Research and development 25,619   18,478
    Sales and marketing 31,544   30,116
    General and administrative 23,204   15,886
    Total stock-based compensation expense $ 84,303   $ 67,704
    Sprout Social, Inc.
    Consolidated Balance Sheets (Unaudited)
    (in thousands, except share and per share data)
           
       
      December 31, 2024   December 31, 2023
    Assets      
    Current assets      
    Cash and cash equivalents $ 86,437   $ 49,760
    Marketable securities 3,745   44,645
    Accounts receivable, net of allowances of $2,169 and $2,177 at December 31, 2024 and December 31, 2023, respectively 84,033   63,489
    Deferred Commissions 20,184   27,725
    Prepaid expenses and other assets 15,816   10,324
    Total current assets 210,215   195,943
    Marketable securities, noncurrent   3,699
    Property and equipment, net 10,951   11,407
    Deferred commissions, net of current portion 51,653   26,240
    Operating lease, right-of-use asset 11,326   8,729
    Goodwill 121,315   121,404
    Intangible assets, net 21,914   28,065
    Other assets, net 967   1,098
    Total assets $ 428,341   $ 396,585
    Liabilities and Stockholders’ Equity      
    Current liabilities      
    Accounts payable $ 6,984   $ 6,933
    Deferred revenue 178,585   140,536
    Operating lease liability 3,747   3,948
    Accrued wages and payroll related benefits 20,567   18,362
    Accrued expenses and other 10,869   11,260
    Total current liabilities 220,752   181,039
    Revolving credit facility 25,000   55,000
    Deferred revenue, net of current portion 1,101   920
    Operating lease liability, net of current portion 14,543   15,083
    Other non-current liabilities 351   351
    Total liabilities 261,747   252,393
           
    Stockholders’ equity      
           
    Class A common stock, par value $0.0001 per share; 1,000,000,000 shares authorized; 54,219,684 and 51,277,740 shares issued and outstanding, respectively, at December 31, 2024; 52,133,594 and 49,241,563 shares issued and outstanding, respectively, at December 31, 2023 4   4
    Class B common stock, par value $0.0001 per share; 25,000,000 shares authorized; 6,687,582 and 6,480,638 shares issued and outstanding, respectively, at December 31, 2024; 7,201,140 and 6,994,196 shares issued and outstanding, respectively, at December 31, 2023 1   1
    Additional paid-in capital 558,391   471,789
    Treasury stock, at cost (37,422)   (35,113)
    Accumulated other comprehensive loss 3   (77)
    Accumulated deficit (354,383)   (292,412)
    Total stockholders’ equity 166,594   144,192
    Total liabilities and stockholders’ equity $ 428,341   $ 396,585
    Sprout Social, Inc.
    Consolidated Statements of Cash Flows (Unaudited)
    (in thousands)
           
      Three Months Ended December 31,
       2024     2023 
    Cash flows from operating activities      
    Net loss $ (14,417)   $ (20,077)
    Adjustments to reconcile net loss to net cash provided by operating activities      
    Depreciation and amortization of property, equipment and software 1,064   835
    Amortization of line of credit issuance costs 51   52
    Accretion of discount on marketable securities (23)   (470)
    Amortization of acquired intangible assets 1,474   1,604
    Amortization of deferred commissions 4,698   7,518
    Amortization of right-of-use operating lease asset 467   425
    Stock-based compensation expense 22,453   18,659
    Provision for accounts receivable allowances 236   835
    Gain on lease modification (1,570)  
    Tax expense due to change in valuation allowance from business acquisition   1,134
    Changes in operating assets and liabilities, excluding impact from business acquisition      
    Accounts receivable (29,908)   (19,235)
    Prepaid expenses and other current assets (729)   3,979
    Deferred commissions (13,101)   (14,522)
    Accounts payable and accrued expenses 4,650   (473)
    Deferred revenue 29,475   18,051
    Lease liabilities (678)   (919)
    Net cash provided by (used in) operating activities 4,142   (2,604)
    Cash flows from investing activities      
    Expenditures for property and equipment (888)   (629)
    Payments for business acquisition, net of cash acquired   143
    Proceeds from maturity of marketable securities 4,900   32,657
    Net cash provided by investing activities 4,012   32,171
    Cash flows from financing activities      
    Borrowings from line of credit  
    Repayments of line of credit (5,000)   (20,000)
    Payments for line of credit issuance costs   (208)
    Proceeds from employee stock purchase plan 718   912
    Employee taxes paid related to the net share settlement of stock-based awards (309)   (537)
    Net cash used in financing activities (4,591)   (19,833)
    Net increase in cash, cash equivalents, and restricted cash 3,563   9,734
    Cash, cash equivalents, and restricted cash      
    Beginning of period 86,855   43,961
    End of period $ 90,418   $ 53,695
    Sprout Social, Inc.
    Consolidated Statements of Cash Flows (Unaudited)
    (in thousands)
         
      Twelve Months Ended December 31,
       2024     2023
    Cash flows from operating activities    
    Net loss $ (61,971) $ (66,427)
    Adjustments to reconcile net loss to net cash provided by operating activities    
    Depreciation and amortization of property, equipment and software 3,890   3,137
    Amortization of line of credit issuance costs 206   86
    Accretion of discount on marketable securities (406)   (3,203)
    Amortization of acquired intangible assets 6,151   3,541
    Amortization of deferred commissions 16,347   26,582
    Amortization of right-of-use operating lease asset 1,827   1,553
    Stock-based compensation expense 84,303   67,704
    Provision for accounts receivable allowances 1,709   2,418
    Gain on lease modification (1,570)  
    Changes in operating assets and liabilities, excluding impact from business acquisition    
    Accounts receivable (22,253)   (26,982)
    Prepaid expenses and other current assets (5,452)   444
    Deferred commissions (34,219)   (40,540)
    Accounts payable and accrued expenses 3,124   (226)
    Deferred revenue 38,230   41,918
    Lease liabilities (3,595)   (3,549)
    Net cash provided by operating activities 26,321   6,456
    Cash flows from investing activities    
    Expenditures for property and equipment (2,950)   (2,073)
    Payments for business acquisition, net of cash acquired (1,409)   (145,636)
    Purchases of marketable securities   (63,085)
    Proceeds from maturity of marketable securities 45,085   118,621
    Proceeds from sale of marketable securities   5,538
    Net cash provided by (used in) investing activities 40,726   (86,635)
    Cash flows from financing activities    
    Borrowings from line of credit   75,000
    Repayments of line of credit (30,000)   (20,000)
    Payments for line of credit issuance costs   (1,031)
    Proceeds from exercise of stock options 29   29
    Proceeds from employee stock purchase plan 1,956   2,339
    Employee taxes paid related to the net share settlement of stock-based awards (2,309)   (2,380)
    Net cash (used in) provided by financing activities (30,324)   53,957
    Net increase (decrease) in cash, cash equivalents, and restricted cash 36,723   (26,222)
    Cash, cash equivalents, and restricted cash    
    Beginning of period 53,695   79,917
    End of period $ 90,418   $ 53,695

    The following schedule reflects our non-GAAP financial measures and reconciles our non-GAAP financial measures to the related GAAP financial measures (in thousands, except per share data):

    Reconciliation of Non-GAAP Financial Measures              
                   
      Three Months Ended December 31,   Twelve Months Ended December 31,
       2024     2023     2024     2023 
    Reconciliation of Non-GAAP gross profit              
    Gross profit $ 83,677   $ 72,623   $ 314,433   $ 257,375
    Stock-based compensation expense 1,046   895   3,936   3,224
    Amortization of acquired developed technology 705   705   2,820   1,175
    Restructuring charges 62     62  
    Non-GAAP gross profit $ 85,490   $ 74,223   $ 321,251   $ 261,774
                   
    Reconciliation of Non-GAAP operating income (loss)            
    Loss from operations $ (13,677)   $ (18,223)   $ (60,356)   $ (69,277)
    Stock-based compensation expense 22,453   18,659   84,303   67,704
    Acquisition-related expenses   51     4,272
    Amortization of acquired intangible assets 1,212   1,213   4,851   2,022
    Restructuring charges 3,020     3,020  
    Gain on lease modification (1,570)     (1,570)  
    Non-GAAP operating income $ 11,438   $ 1,700   $ 30,248   $ 4,721
                   
    Reconciliation of Non-GAAP net income (loss)              
    Net loss $ (14,417)   $ (20,077)   $ (61,971)   $ (66,427)
    Stock-based compensation expense 22,453   18,659   84,303   67,704
    Acquisition-related expenses   51     4,272
    Amortization of acquired intangible assets 1,212   1,213   4,851   2,022
    Restructuring charges 3,020     3,020  
    Gain on lease modification (1,570)     (1,570)  
    Tax expense due to change in valuation allowance from business acquisition   1,134    
    Non-GAAP net income $ 10,698   $ 980   $ 28,633   $ 7,571
                   
    Reconciliation of Non-GAAP net income (loss) per share            
    Net loss per share attributable to common shareholders, basic and diluted $ (0.25)   $ (0.36)   $ (1.09)   $ (1.19)
    Stock-based compensation expense 0.39   0.34   1.48   1.22
    Acquisition-related expenses       0.08
    Amortization of acquired intangible assets 0.03   0.02   0.09   0.03
    Restructuring charges 0.05     0.05  
    Gain on lease modification (0.03)     (0.03)  
    Tax expense due to change in valuation allowance from business acquisition   0.02    
    Non-GAAP net income per share $ 0.19   $ 0.02   $ 0.50   $ 0.14
                   
    Reconciliation of Non-GAAP free cash flow              
    Net cash provided by (used in) operating activities $ 4,142   $ (2,604)   $ 26,321   $ 6,456
    Expenditures for property and equipment (888)   (629)   (2,950)   (2,073)
    Acquisition-related costs   1,366     4,272
    Interest paid on credit facility 621   1,588   3,635   1,588
    Payments related to restructuring charges 2,682     2,682  
    Non-GAAP free cash flow $ 6,557   $ (279)   $ 29,688   $ 10,243

    The MIL Network

  • MIL-OSI USA: Cantwell-Led Fusion Energy Commercialization Commission Releases Roadmap to Secure American Leadership in Fusion Energy

    US Senate News:

    Source: United States Senator for Washington Maria Cantwell
    02.25.25
    Cantwell-Led Fusion Energy Commercialization Commission Releases Roadmap to Secure American Leadership in Fusion Energy
    Cantwell: Expanding fusion can help “meet our growing electricity demand, lower emissions, & increase export opportunities”
    WASHINGTON, D.C. – Yesterday, the Commission on the Scaling of Fusion Energy, which is co-chaired by U.S. Senator Maria Cantwell (D-WA), ranking member of the Senate Committee on Commerce, Science, and Transportation, and senior member of the Senate Finance Committee, and Senate Energy and Natural Resources Committee; Sen. Jim Risch (R-ID), chair of the Senate Foreign Relations Committee; and Ylli Bajraktari, President, Special Competitive Studies Project (SCSP), released a preliminary report titled “Fusion Power: Enabling 21st Century American Dominance.”
    “Fusion could provide vast amounts of the type of power we need to keep electricity prices down and increase America’s economic competitiveness,” said Sen. Cantwell. “This preliminary report provides a roadmap for how the United States could lead the world in fusion commercialization in order to meet our growing electricity demand, lower emissions, and increase export opportunities.”
    Fusion, the same process that powers the sun, typically utilizes an inexhaustible supply of water as its fuel, and produces negligible atmospheric emissions and zero greenhouse gas emissions. Fusion reactors cannot melt down, and do not generate the high-level, long-lasting radioactive waste associated with nuclear fission reactors.
    The Commission’s recommendations are organized into three categories:
    Declare Fusion a National Security Priority: The United States should prioritize fusion energy development. A presidential executive order should articulate a National Fusion Goal and establish a national fusion strategy led by the Department of Energy (DOE), with a 90-day action plan to streamline regulations, organize public and private stakeholders, and align the necessary resources. This will ensure U.S. leadership in fusion energy, which is vital for national prosperity and security.
    Establish Fusion Leadership and Drive Commercialization: A political appointee at the DOE should be appointed as the national “Fusion Lead” and be empowered to implement the Fusion Executive Order (EO). This senior leader should report to the Secretary and oversee existing DOE fusion commercialization programs, develop the 90-day action plan, and dismantle bureaucratic obstacles.
    Strategic Investment to Win the Fusion Race: The United States will not be able to achieve fusion power unless it invests in the fundamental building blocks of commercial fusion: infrastructure, supply chain, and talent. To outpace China, the United States should make a one-time investment towards these strategic assets, de-risk multiple commercial fusion pathways, and sustain basic research to cultivate the next generation of fusion science.
    The 13-member Commission on the Scaling of Fusion Energy, first announced in Fall 2023 at SCSP’s Global Emerging Technology Summit, aims to position the United States not only as the leader in fusion science but also in its scaling as the technology matures. The Commission will hold sessions throughout 2025, culminating in its final report later this year.
    This effort represents a step towards ensuring U.S. leadership in a transformative technology, with implications for national security, economic prosperity, and energy independence. The Commission’s work will lay the foundation for a future where fusion energy could be the key pillar of global energy infrastructure.
    Sen. Cantwell is a leading Senate champion for the development and deployment of fusion energy.
    In July 2024, Sen. Cantwell hosted a Pacific Northwest Energy Summit, joining U.S. Senator Ron Wyden (D-OR) and regional energy stakeholders to discuss technological and policy solutions that will ensure NW ratepayers and our regional economy continue to benefit from abundant, affordable, and reliable clean energy. More than 200 business, government, and non-profit energy professionals attended the event.
    In May 2023, Sen. Cantwell applauded Everett-based Helion Energy’s announcement that they plan to be the first company in the world to generate and sell electricity from a fusion reactor.
    Thanks to leading fusion companies like Helion, as well as Everett-based Zap and Seattle-based Avalanche, many consider the Puget Sound region to be the world’s biggest fusion energy hub.
    During a Senate hearing in April 2023, Sen. Cantwell pressed Department of Energy Secretary Jennifer Granholm about plans to expand federal support for fusion research.
    At an Energy Committee hearing in September 2022, Sen. Cantwell asked fusion experts like Dr. Scott Hsu, Lead Fusion Coordinator for the Department of Energy, and Professor Steven Cowley, Director of the Princeton Plasma Physics Laboratory, about what more we can be doing to boost fusion R&D and make sure we can manufacture fusion components domestically.

    MIL OSI USA News

  • MIL-OSI Economics: Isabel Schnabel: No longer convenient? Safe asset abundance and r*

    Source: European Central Bank

    Keynote speech by Isabel Schnabel, Member of the Executive Board of the ECB, at the Bank of England’s 2025 BEAR Conference

    London, 25 February 2025

    Over the past few years, global bond investors have fundamentally reappraised the expected future course of monetary policy.

    Even as inflation has receded and policy restriction has been dialled back, current market prices suggest that maintaining price stability will require higher real interest rates in the future than before the pandemic.

    In my remarks today, I will argue that the shift in market expectations about the level of r* – the rate to which the economy is expected to converge in the long run once current shocks have run their course – is consistent with two sets of observations.

    The first is that the era during which risks to inflation have persistently been to the downside is likely to have come to an end.

    Growing geopolitical fragmentation, climate change and labour scarcity pose measurable upside risks to inflation over the medium to long term. This is especially true as the recent inflation surge may have permanently scarred consumers’ inflation expectations and may have lowered the bar for firms to pass through adverse cost-push shocks to consumer prices.

    The second observation is that we are transitioning from a global “savings glut” towards a global “bond glut”.

    Persistently large fiscal deficits and central bank balance sheet normalisation are gradually reducing the safety and liquidity premia that investors have long been willing to pay to hold scarce government bonds. The fall in the “convenience yield”, in turn, reverses a key factor that had contributed to the decline in real long-term interest rates, and hence r*, during the 2010s.

    The implications for monetary policy are threefold.

    First, a higher r* calls for careful monitoring of when monetary policy ceases to be restrictive. Second, central bank balance sheet policies may themselves affect the level of r* through the convenience yield, making them potentially less effective than previously thought. Third, because central bank reserves also offer convenience services to banks, it is optimal to provide reserves elastically on demand as quantitative tightening reduces excess liquidity.

    Upward shift in r* signals lasting change in the inflation regime

    Starting in 2021, long-term government bond yields rose measurably across advanced economies. Today, the ten-year yield of a German government bond is about two and a half percentage points higher than in late 2021 (Slide 2, left-hand side).

    What is remarkable about the rise in nominal bond yields in the euro area over this period is that it was not driven by a change in inflation compensation. Investors’ views about future inflation prospects are broadly the same today as they were three years ago (Slide 2, right-hand side).

    Rather, nominal interest rates rose because real interest rates increased. Euro area real long-term rates are now trading at a level that is substantially higher than the level prevailing during most of the post-2008 global financial crisis period (Slide 3, left-hand side).

    Part of the rise in real long-term interest rates is a mechanical response to the tightening of monetary policy.

    Long-term interest rates are an average of expected short-term interest rates over the lifetime of the bond, plus a term premium. So, when we raised our key policy rates in response to the surge in inflation, the average real rate expected to prevail over the next ten years increased.[1]

    What is more striking, however, is that investors also fundamentally revised the real short-term rate expected to prevail once inflation has sustainably returned to our target. This rate is typically taken as a proxy for the natural rate of interest, or r*.

    The real one-year rate expected in four years (1y4y), for example, is now at the highest level since the sovereign debt crisis (Slide 3, right-hand side). Even at very distant horizons, such as in nine years, the expected real short-term rate (1y9y) has increased measurably in recent years.

    To a significant extent, these developments reflect a genuine reappraisal of the real equilibrium interest rate that is consistent with our 2% inflation target. A rise in the term premium, which is the excess return investors demand for the uncertainty surrounding the future interest rate path, can explain less than half of the change in the real 1y4y rate.[2]

    These forward rates have also remained surprisingly stable since 2023, with a standard deviation of around just 15 basis points, despite the measurable decline in inflation, the protracted weakness in aggregate demand and the series of structural headwinds facing the euro area.

    We are seeing a similar upward shift in model-based estimates of r*. According to estimates by ECB economists, the natural rate of interest in the euro area has increased appreciably over the past two years, and even more so than what market-based real forward rates would suggest (Slide 4).[3]

    This result is robust across many models and even holds when accounting for the significant uncertainty surrounding these estimates. In other words, for drawing conclusions about the directional change of r* from the rise in market and model-based measures, the actual rate level is largely irrelevant.

    What matters is the direction of travel. And that is unambiguous: we are unlikely to return to the pre-pandemic macroeconomic environment in which central banks had to bring real rates into deeply negative territory to deliver on their price stability mandate. This suggests that the nature of the inflation process is likely to have changed lastingly.

    Real interest rates are only loosely tied to trend growth

    Why do markets expect such a trend reversal for real interest rates in the euro area?

    One answer is that some of the forces that weighed on inflation during the 2010s are now reversing.

    Globalisation is a case in point. The integration of China and other emerging market economies into the global production network and the broad-based decline in tariff and non-tariff barriers were important factors reducing price pressures in advanced economies over several decades.[4]

    Today, protectionist policies, the weaponisation of critical raw materials and geopolitical fragmentation are increasingly dismantling the foundations on which trade improved the welfare of consumers worldwide.

    These forces can be expected to have first-order effects on inflation.

    European gas prices, for example, are up by 65% compared with a year ago despite the significant decline over recent days. Oil prices, too, have increased since September of last year, in part reflecting the marked depreciation of the euro.

    While commodity prices are inherently volatile, and may reverse quickly, other deglobalisation factors, such as reshoring and the lengthening of supply chains, are likely to increase price pressures more lastingly.

    And yet, the persistent rise in real forward rates poses a conundrum in the euro area.

    The reason is that increases in long-term real interest rates are typically thought of as being associated with improvements on the supply side of the economy, such as productivity growth, the labour force and the capital stock.

    At present, however, these factors do not point towards an increase in r* in the euro area.

    Potential growth has generally been revised lower, not higher, as many of the factors currently holding back consumption and especially investment are likely to be structural in nature, such as a rapidly ageing population and deteriorating competitiveness.

    The weak link between the structural factors driving potential growth and r* is, however, not exceptional from a historical perspective.

    Indeed, over time there has been little evidence of a stable relationship between real interest rates and drivers of potential growth, such as demographics and productivity.[5] They have had the expected relationship in some subsamples but not in others.[6]

    Similarly, in the most popular framework for estimating r*, the seminal model by Laubach and Williams, potential growth has played an increasingly subordinated role in explaining why the natural rate of interest has remained at a depressed level in the United States following the global financial crisis (Slide 5, left-hand side).[7]

    Rather, the persistence in the decline in r* is explained to a large extent by a residual factor, which lacks economic interpretation.

    Moreover, if growth was the main driver of r*, then one would expect all real rates in the economy to adjust in a similar way. But while real rates on safe assets have declined since the early 1990s, the return on private capital has remained relatively constant.[8]

    Decline in the convenience yield is pushing r* up

    A growing body of research attempts to reconcile these puzzles. Many studies attribute a significant role to the money-like convenience services that safe and liquid assets, such as government bonds, provide to market participants.

    The yield that investors are willing to forgo in equilibrium for these services is what economists call the “convenience yield”.[9]

    This yield, in turn, critically depends on the net supply of safe assets: When these are scarce, investors are willing to pay a premium to hold them, depressing the real equilibrium rate of interest. And when they are abundant, the premium falls, putting upward pressure on r*.

    New research by economists at the Board of Governors of the Federal Reserve System shows how incorporating the convenience yield into the Laubach and Williams framework significantly improves the explanatory power of the model.[10]

    In fact, the convenience yield can explain most of the residual factor and is estimated to have caused a large part of the secular decline in the real natural rate in the United States (Slide 5, right-hand side).

    Liquidity requirements that regulators imposed on banks in the wake of the global financial crisis, the Federal Reserve’s balance sheet policies and the integration of many large emerging market economies into the global economy have led to an unprecedented increase in the demand for safe and liquid assets, driving up their convenience yield.[11]

    These findings are in line with earlier research showing that the convenience yield has played an equally important role in depressing the real equilibrium rate in many other advanced economies, including the euro area, during the 2010s.[12]

    This process is now reversing. According to the work by the Federal Reserve economists, r* has recently increased visibly, contrary to what the model without a convenience yield would suggest.

    Asset swap spreads are a good indicator of the convenience yield. Both interest rate swaps and government bonds are essentially risk-free assets, so they should in principle yield the same return.

    For a long time, this has been the case: before the start of quantitative easing (QE) in the euro area in 2015, the spread between a ten-year German Bund and a swap of equivalent maturity was close to zero on average (Slide 6, left-hand side).

    Over time, however, with the start of QE and the parallel fiscal consolidation by governments reducing the net supply of government bonds in the market, the premium that investors were willing to pay to secure their convenience services rose measurably. At the peak, ten-year Bunds were trading nearly 80 basis points below swap rates.

    But since about mid-2022 the asset swap spread has persistently narrowed. In October of last year it turned positive for the first time in ten years, and it now stands close to the pre-QE average again.

    Other measures of the convenience yield paint a similar picture. The spread between ten-year bonds issued by the Kreditanstalt für Wiederaufbau (KfW) and German Bunds has narrowed from about
    -80 basis points in October 2022 to just -30 basis points today (Slide 6, right-hand side).[13]

    Furthermore, in the repo market, we have observed a steady and measurable rise in overnight rates and a convergence across collateral classes (Slide 7, left-hand side).[14]

    Over the past few years, transactions secured by German government collateral, in particular, were trading at a significant premium over others. This premium has declined considerably, reflecting a reduction in collateral scarcity.

    Finally, in the United States, the spread between AAA corporate bonds and US Treasuries has declined from almost 100 basis points in 2022 to 40 basis points today (Slide 7, right-hand side). It currently stands close to its historical low.

    Global savings glut has turned into a global bond glut

    All this suggests that, today, market participants value the liquidity and safety services of government bonds less than they did in the past, as the net supply of government bonds has increased and continues to increase at a notable pace.

    In Germany and the United States, for example, the sovereign bond free float as a share of the outstanding volume has increased by more than ten percentage points over the past three years (Slide 8, left-hand side). It is projected to steadily increase further in the coming years.

    So, the global savings glut appears to have turned into a global bond glut, which reduces the marginal benefit of holding government bonds.

    There are several factors contributing to the rise in the bond free float.[15]

    First, and most importantly, net borrowing by governments remains substantial. The public deficit is estimated to have been around 5% of GDP across advanced economies last year, and it is expected to decline only marginally in the coming years (Slide 8, right-hand side).

    Second, rising geopolitical fragmentation is likely to be contributing to a drop in demand for government bonds in some parts of the world.

    In the United States, for example, there has been a marked decline in the share of foreign official holdings of US Treasury securities since the global financial crisis (Slide 9, left-hand side). It is now at its lowest level in more than 20 years.[16] The US Administration’s attempt to reduce the current account deficit is bound to further depress foreign holdings of US Treasuries.

    Third, central banks are in the process of normalising their balance sheets (Slide 9, right-hand side). Unlike when central banks announced large-scale asset purchases, the effects of quantitative tightening (QT) on yields are likely to materialise only over time, as many central banks take a gradual approach when reducing the size of their balance sheets.

    Higher r* calls for cautious approach to rate easing

    These developments have three important implications for monetary policy.

    One is that central banks are dialling back policy restriction in an environment in which structural factors are putting upward pressure on the real equilibrium rate. Recent analysis by the International Monetary Fund (IMF), for example, suggests that a fall in the convenience yield to pre-2000 average levels could raise natural rates by about 70 basis points.[17]

    While a significant part of these effects may have already materialised, other factors could push real rates up further over the medium term. The IMF projects that, in the coming years, overall global investment – public and private – will reach the highest share of GDP since the 1980s, also reflecting borrowing needs associated with the digital and green transitions as well as defence spending.

    Recent global initiatives aimed at boosting the development and use of artificial intelligence underscore these projections. Overall, these forces may well be larger than those that continue to weigh on the real equilibrium rate, such as an ageing population.

    Central banks, therefore, need to proceed cautiously. We do not fully understand how the pervasive changes to our economies are affecting the steady state, or what the path to the new steady state will look like.

    In this environment, the most appropriate way to conduct monetary policy is to look at the incoming data to assess how fast, and to what extent, changes to our key policy rates are being transmitted to the economy.

    For the euro area, this assessment suggests that, over the past year, the degree of policy restraint has declined appreciably – to a point where we can no longer say with confidence that our policy is restrictive.

    According to the most recent bank lending survey, for example, 90% of banks say that the general level of interest rates has no impact on the demand for corporate loans, with 8% saying that it contributes to boosting credit demand (Slide 10, left-hand side). This is a marked shift from a year ago when a third of all banks reported that interest rates were weighing on credit demand.

    For mortgages, the evidence is even more striking. Today almost half of the banks report that the level of interest rates supports loan demand, while a year ago more than 40% said the opposite. As a result, a net 42% of banks report an increase in the demand for mortgages, close to the historical high.

    Survey evidence is gradually showing up in actual lending data. Credit to firms expanded by 1.5% in December, the highest rate in a year and a half, and credit to households for house purchases grew by 1.1% (Slide 10, right-hand side).

    Strong bank balance sheets are contributing to the recovery and, given the lags in policy transmission, further easing is still in the pipeline.

    Lending conditions are also relatively favourable from the perspective of borrowers. The spread between the composite cost of borrowing for households and sovereign bond yields is well below the level seen over most of the 2010s and is now close to the historical average (Slide 11).[18]

    And while some maturing loans from the period of very low interest rates will still need to be refinanced at higher rates, over time this debt has declined in real terms and interest payments as a fraction of net income are buffered by rising nominal wages.

    Overall, therefore, it is becoming increasingly unlikely that current financing conditions are materially holding back consumption and investment. The fact that growth remains subdued cannot and should not be taken as evidence that policy is restrictive.

    As the ECB’s most recent corporate telephone survey suggests, the continued weakness in manufacturing is increasingly viewed by firms as structural, reflecting a combination of high energy and labour costs, an overly inhibitive and uncertain regulatory environment and increased import competition, especially from China.[19]

    Such structural headwinds reduce the economy’s sensitivity to changes in monetary policy.

    QE’s impact on r* is reducing its effectiveness

    The second implication from the impact of the convenience yield on r* is related to the use of balance sheet policies.

    If QE raises the convenience yield by reducing the net supply of government bonds, it may ultimately lower the real equilibrium interest rate. Importantly, this channel – the convenience yield channel – is distinct from the term premium channel.[20]

    So, doing QE could be like chasing a moving target.

    It reduces long-run rates by compressing the term premium.[21] But by making investors willing to pay a higher safety premium when the supply of safe assets shrinks, it may also reduce the interest rate level below which monetary policy stimulates growth and inflation.

    This can also be seen by looking at how QE changes the balance of savings and investments. Fiscal deficits absorb private savings and thereby increase r*. By doing QE, central banks absorb fiscal deficits and thereby lower r*.

    In other words, central bank balance sheet policies may be less effective than previously thought.[22] This could be an additional factor explaining why large-scale asset purchases did not succeed in bringing inflation back to 2% before the pandemic.

    Of course, the same logic holds true when central banks reduce their balance sheets.

    If QE contributed to depressing r*, QT will raise it. Any rise in real rates may then be less consequential for growth and inflation. It would then be misguided to compensate for higher long-term interest rates resulting from QT with lower short-term rates.

    This is indeed what recent research suggests: QT announcements tend to cause a significant decline in the convenience yield of safe assets.[23]

    There is one caveat, however.

    QE and QT are implemented by issuing and absorbing central bank reserves, which themselves are safe assets – in fact, reserves are the economy’s ultimate safe asset because they are free of liquidity and interest rate risk.[24]

    Banks therefore highly value the convenience services of central bank reserves. So, when evaluating the effects of central bank balance sheet policies on r*, it is necessary to consider both the asset and liability side.

    Research by economists from the Bank of England does exactly that.[25] They show that the effects of QT on the real equilibrium rate depend on the relative strength of two factors.

    One is the effect on the bond convenience yield, which causes r* to rise as the supply of government bonds increases.

    The other is the effect on the convenience yield of reserves. That effect is highly non-linear: when reserves are scarce, banks are willing to pay a high mark-up on wholesale interest rates, as was evident in the United States in 2019 when repo rates surged strongly.

    So, if QT leads to a scarcity of reserves, it may cause the overall convenience yield to rise, and hence equilibrium rates to fall.

    Convenience of reserves and the ECB’s operational framework

    At the ECB, we took this factor into account when we reviewed our operational framework last year.[26] This is the third implication for monetary policy.

    The new framework allows banks to demand as many reserves as they find optimal at a spread that is 15 basis points above the rate which the ECB pays to banks when they deposit their excess reserves with us. So, the opportunity cost of holding reserves is comparatively small, given the convenience services reserves provide to banks.

    In addition, our framework allows banks themselves to generate an increase in safe assets – by pledging non-high quality liquid assets (non-HQLA) in our lending operations. In doing so, banks on average generate € 0.92 of net HQLA for every euro that they borrow from the Eurosystem.[27]

    Our framework therefore recognises that years of crises, more stringent regulatory requirements and the advance of new technologies – some of which increase the risk of “digital” bank runs – imply that banks may wish to hold larger liquidity buffers than they historically have done.

    Supplying central bank reserves elastically will ensure that reserves will not become scarce as balance sheet normalisation proceeds. And if banks access our standard refinancing operations when they are in need of liquidity, they will also not have to adjust their lending activities in response to the decline in reserves, as is sometimes feared.[28]

    For now, the recourse to our lending operations has been limited, as there is still ample excess liquidity. But as we transition over the coming years to a world in which reserves are less abundant, banks will increasingly start borrowing reserves via our operations.

    Three ideas could be explored to make this transition as smooth as possible.

    First, regular testing requirements in the counterparty framework could help ensure operational readiness while also allowing counterparties to become more comfortable with participating in our operations. A lack of operational readiness was one of the factors contributing to the March 2023 turmoil in the United States.[29]

    Second, and related, obtaining central bank funding requires thorough collateral management, especially if the collateral framework is as broad as the Eurosystem’s. For non-HQLA collateral, in particular, the pricing and due diligence process can be operationally complex and time-consuming.

    For this reason, central banks sometimes require counterparties to pre-position collateral to ensure that funding can be readily obtained.[30] In the euro area, some banks already pre-position collateral voluntarily, in particular non-marketable collateral which cannot be used in private repo markets (Slide 12, left-hand side).

    Banks could be further encouraged to mobilise with the central bank the collateral that is eligible but currently stays idle on their balance sheets. This would increase operational readiness, mitigate financial stability risks and reduce precautionary reserve demand as banks would have higher certainty that they can access central bank liquidity at short notice.

    In the Eurosystem, given its broad collateral framework, such an approach may be more effective in helping banks adapt their liquidity management to the characteristics of a demand-driven operational framework compared with a blanket requirement to pre-position collateral.

    Finally, in some jurisdictions central bank operations are fully integrated into the platforms commonly used by banks to operate in private repo markets.

    This offers banks a number of advantages, including seamless access to transactions with the market and with the central bank, and – depending on the design of clearing arrangements and accounting rules – it could potentially allow banks to net out their positions, thereby freeing up valuable balance sheet space.

    Offering banks the possibility to access Eurosystem refinancing operations through a centrally cleared infrastructure could contribute to making our operations more economical in an environment in which dealer balance sheets are increasingly constrained (Slide 12, right-hand side).[31]

    The design of such arrangements should preserve equal treatment across our diverse range of counterparties, regardless of their size, jurisdiction and business model, maintain the possibility to mobilise a broad range of collateral and be compatible with our risk control framework.

    Further reflection is needed on these considerations, including a comprehensive assessment of the benefits and costs.

    Conclusion

    Let me conclude.

    The shocks experienced since the pandemic led to an abrupt end of the secular downward trend in real interest rates. Whether this will be merely an interlude, or the beginning of a new era, is inherently difficult to predict.

    But looking at the ongoing transformational shifts in the balance of global savings and investments, as well as at the fundamental challenges facing our societies today, higher real interest rates seem to be the most likely scenario for the future.

    This has implications for our monetary policy. Central banks will need to adjust to the new environment, both to secure price stability over the medium term and to implement monetary policy efficiently.

    Thank you.

    MIL OSI Economics

  • MIL-OSI Asia-Pac: Prakriti 2025 – International Conference on Carbon Markets

    Source: Government of India (2)

    Prakriti 2025 – International Conference on Carbon Markets

    UN Goodwill Ambassador & Actor Dia Mirza attends Prakriti 2025

    Prakriti 2025: International Conference on Carbon Markets Concludes with Insights from National, International, and Government Experts

    Posted On: 25 FEB 2025 5:53PM by PIB Delhi

    PRAKRITI 2025 (Promoting Resilience, Awareness, Knowledge, and Resources for Integrating Transformational Initiatives), the International Conference on Carbon Markets, successfully concluded on its second day, bringing together national and international experts, policymakers, industry leaders, researchers, and practitioners. The conference was inaugurated on February 24, 2025, by Shri Manohar Lal, Hon’ble Minister of Power and Housing & Urban Affairs. As a flagship initiative of the Government of India, organized by the Bureau of Energy Efficiency under the patronage of the Ministry of Power and the Ministry of Environment, Forest and Climate Change, PRAKRITI 2025 served as a premier platform for in-depth discussions on global carbon market trends, challenges, and future pathways.

          Ms. Dia Mirza, Actor, Producer, National Goodwill Ambassador for United Nations graced the event with her presence. She participated in an impactful fireside chat moderated by Mr. Saurabh Diddi, Director, Bureau of Energy Efficiency. Speaking of her role in making a change in the climate change scenario, she said that, As an individual, I have the capacity to change the way I live and hopefully thereby bring some change in the world. Big change will only occur when it starts from the top down because behaviours sometimes take hundreds of years to change.” She commended the Government of India for its initiatives under LiFE (Lifestyle for Environment), highlighting its role in promoting mindful consumption and leading a global movement. Additionally, she emphasized the importance of engaging children and youth to drive meaningful change in climate conversations. Concluding the interview, she shared her vision for sustainability, stating, “My dream sustainability project, if finances didn’t have any upper limit, would be one, to eradicate each and every unit of single use plastics, and two, a scenario where every resource comes in the circular economy.”

      

          Mr. Thomas Kerr, Lead Climate Change Specialist, World Bank chaired and moderated the opening plenary session on Private Sector Perspectives on Indian Carbon Market (ICM). He emphasized that the Indian Carbon Market does not operate in isolation, as global carbon pricing policies will influence India’s industries. Businesses must prepare for these shifts. He highlighted the impact of the European Union’s Carbon Border Adjustment Mechanism (CBAM) on Indian exports, particularly in steel, aluminium, and other high-emission industries, stating, “The European Union’s Carbon Border Adjustment Mechanism (CBAM) will impact Indian exports, particularly in steel, aluminium, and other high-emission industries. This calls for urgent action in domestic carbon markets.” Encouraging India’s active participation, he added, “If you build it, they will come.”

           Mr. Ashok Lavasa, Former Finance Secretary and Government Official, delivered a thematic address on Governance, Transparency, and Accountability in Climate Finance and Carbon Markets. His speech highlighted the complexities of global carbon markets and the challenges India faces in developing a robust system. Emphasizing key factors for success, he stated, “Strong MRV frameworks, fair benefit distribution, and strategic market alignment are crucial to India’s success in the carbon economy. International collaboration is necessary, but India must develop policies tailored to its own needs and challenges.”

           The second day of the conference featured thematic addresses and a series of plenary sessions led by senior government officials and industry experts. Key discussions focused on: Incentivizing Renewable Energy developers through Carbon Markets, Development in Article 6 and Opportunities for India, Bringing Price Transparency in Global Carbon Marketplace, Role of Ecosystem-Based Interventions in Achieving Net-Zero Goals, Climate Tech Startups for Sustainable Development, and Leveraging finance for the deployment of clean technologies.

            The two-day event witnessed robust participation from key Indian ministries, including the Ministry of Power, Ministry of Environment, Forest and Climate Change, and the Ministry of Agriculture, Financial Institutions, Corporates, International NGOs, PSUs, etc. Approximately 80+ experts and 600+ delegates engaged in the conference’s discussion in the last two days, focusing on carbon market mechanisms, policy framework, climate finance and technologies. This demonstrates a coordinated, intergovernmental strategy, fostering synergistic collaboration and broad stakeholder participation, affirming India’s dedication to meet climate goals.

             More than just a conference, Prakriti 2025 has distinguished itself as one of the most comprehensive and significant carbon market events for learning, sharing knowledge, and exploring opportunities for collaboration in the global effort to combat climate change. Prakriti 2025 will build on this momentum, marking a significant milestone in both India’s national climate agenda and the broader international climate discourse.

    About BEE

    The Government of India set up the Bureau of Energy Efficiency (BEE) on March 1, 2002 under the provisions of the Energy Conservation Act, 2001. The mission of the Bureau of Energy Efficiency is to assist in developing policies and strategies with a thrust on self-regulation and market principles, within the overall framework of the Energy Conservation Act, 2001 with the primary objective of reducing the energy intensity of the Indian economy. BEE coordinates with designated consumers, designated agencies and other organizations and recognises, identifies and utilises the existing resources and infrastructure, in performing the functions assigned to it under the Energy Conservation Act. The Energy Conservation Act provides for regulatory and promotional functions.

    ****

    JN/SK

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    MIL OSI Asia Pacific News

  • MIL-OSI Asia-Pac: A National Conference on ‘Sustainable Cooling and Doubling the Rate of Energy Efficiency Improvement,’ was held in New Delhi on Feb. 21-22, 2025

    Source: Government of India (2)

    Posted On: 25 FEB 2025 5:49PM by PIB Delhi

    A National Conference on ‘Sustainable Cooling and Doubling the Rate of Energy Efficiency Improvement,’ was organised in New Delhi on Feb. 21-22, 2025. The two-day conference was jointly organized by the Bureau of Energy Efficiency (BEE) and the Power Foundation of India (PFI), under the Ministry of Power, Govt. of India.

    The Hon’ble Union Minister of Power and Housing and Urban Affairs, Shri Manohar Lal, inaugurated the Conference. While delivering his inaugural address, he remarked, Energy efficiency is not just an option but a necessity for a cleaner, more sustainable, and economically prosperous future. By doubling the rate of energy efficiency improvement, we can lower costs, enhance productivity, and significantly cut greenhouse gas emissions.”

    The Hon’ble Minister highlighted that India’s power sector has made remarkable progress, with non-fossil fuel capacity reaching 47.15% and emission intensity reduced by 36% – well ahead of our commitments,” he added.

    The Hon’ble Minister also launched a Report titled ‘India Energy Scenario 2023-24’ that provides a comprehensive overview of the country’s energy landscape, trends, and progress in energy efficiency and sustainability.

    The Hon’ble Minister also unveiled a set of Energy-Efficient Retrofit manuals and flyers designed to offer a structured approach for evaluating, planning, and carrying out retrofits in existing commercial and residential buildings. These manuals will serve as a crucial resource for States/UTs, policymakers, and stakeholders in promoting energy efficiency initiatives.

    Hon’ble Minister of State for Power and New and Renewable Energy, Shri Shripad Naik was also present at the inauguration. In his keynote address, he said, “India stands at a crucial juncture where increasing energy demand must be balanced with ambitious climate goals. As the world’s third-largest energy consumer, our commitment to doubling energy efficiency and advancing sustainable cooling is vital for economic growth and climate action. We have met our Nationally Determined Contributions well ahead of time. Under India’s leadership, the G20 and COP28 reinforced the urgency of accelerating energy efficiency globally.”

    Speaking on the occasion, Shri Pankaj Agarwal, Secretary, Ministry of Power, underlined that the G20 Summit in India in 2023 was a pivotal moment in advancing global energy efficiency, highlighting energy efficiency as the ‘first fuel’ and the adoption of the Voluntary Action Plan to double the rate of energy efficiency improvement by 2030 through the New Delhi Leaders’ Declaration (NDLD). He stressed on the need to optimize energy demand from various sectors for doubling the rate of energy savings improvement by 2030.

    To achieve this goal, India’s Energy Intensity (EI) improvement rate, estimated at approximately 2.5% in 2024, will need to increase to 4% by 2030, as per an estimate by the International Energy Agency (IEA).

    While the policies and technologies to achieve the doubling goal are well-recognized and available, greater clarity is needed through stakeholder consultations on measuring energy intensity improvement, attributing energy savings impact, and translating global commitments into actionable steps. There is a pressing need to address rising cooling demand and ensure access to energy-efficient, sustainable cooling solutions. The two-day conference served as a significant step toward advancing discussions, fostering collaboration, and driving actionable solutions in this domain.

    The National Conference brought together key stakeholders from the government, national and international agencies, multilateral organizations, civil society, industry associations, financial institutions, and consumers. Knowledge partners include global organizations such as the IEA, Sustainable Energy for All (SE4All), CLASP, and the International Council on Clean Transportation (ICCT), along with leading Indian think tanks like The Energy and Resources Institute (TERI), the Council for Energy, Environment and Water (CEEW), and the Alliance for an Energy Efficient Economy (AEEE). The Conference featured thematic sessions covering Buildings, Appliances, Industry, Transport, Investment, and Sustainable Cooling.

    More than 50 speakers and 250 delegates were part of the Conference. The two-day National Conference concluded on Feb. 22, 2025.

    About the Bureau of Energy Efficiency:

    The Bureau of Energy Efficiency (BEE), a statutory agency under the Ministry of Power, Government of India, leads efforts to enhance energy efficiency across the economy using various regulatory and promotional tools. The Bureau focuses on developing policies and strategies that emphasize self-regulation and market-driven principles, aiming to reduce the energy intensity of the Indian economy. BEE has launched numerous initiatives to promote energy efficiency in areas such as household lighting, commercial buildings, appliance standards and labelling, demand-side management in agriculture and municipalities, and across SMEs and large industries. It has also begun developing energy consumption norms for industrial sub-sectors and focuses on capacity building for State Designated Agencies (SDAs).

    About Power Foundation of India:

    The Power Foundation of India is a think-tank and a policy advocacy body in the power sector, operating under the Ministry of Power, Govt. of India.

    The Foundation conducts independent, evidence-based research on key issues and challenges within the power sector. Its research covers a wide range of topics, including power generation, transmission, distribution, electricity trading, energy transition, and environmental sustainability.

    Additionally, the Foundation designs and implements campaigns and outreach programs focused on relevant power sector themes.

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    MIL OSI Asia Pacific News

  • MIL-OSI Asia-Pac: “Space economy expected to increase five-fold from 8 bn $ to 44 bn $ in few years making value addition in Indian economy and moving towards Viksit Bharat @2047” says Union Minister Dr. Jitendra Singh

    Source: Government of India

    “Space economy expected to increase five-fold from 8 bn $ to 44 bn $ in few years making value addition in Indian economy and moving towards Viksit Bharat @2047” says Union Minister Dr. Jitendra Singh

    2014 was a pivotal turning point for India’s space journey, Prime Minister Narendra Modi took an out-of-box decision to “unlock” India’s Space sector

    Prime Minister Narendra Modi increased Space budget almost three times from 5,615 crore in 2013-14 to 13,416 crore in 2025-2026: Dr. Singh

    “Jammu & Kashmir emerging as a role model in Agri-tech startups with the success of the Aroma Mission: Purple Revolution” highlights Dr. Jitendra Singh

    Posted On: 25 FEB 2025 5:41PM by PIB Delhi

    “India’s Space economy is expected to increase fivefold from 8 bn $ to 44 bn $ in next few years, making value addition in the Indian economy and moving towards Viksit Bharat in 2047”.

    This was stated here today by Union Minister of State (Independent Charge) for Science and Technology, Minister of State (Independent Charge) for Earth Sciences, MoS PMO, Department of Atomic Energy and Department of Space and MoS Personnel, Public Grievances and Pensions Dr. Jitendra Singh while addressing the “Business Conclave” organized by the Times Network in New Delhi.

    The Minister highlighted the remarkable progress achieved by the Indian space sector, citing the increased space budget as a key factor driving this success. He noted that under the leadership of Prime Minister Narendra Modi, the space budget has almost tripled—from ₹5,615 crore in 2013-14 to ₹13,416 crore in 2025-2026, reflecting the government’s commitment to fostering growth in the space sector.

    Dr. Jitendra Singh pointed to 2014 as a pivotal turning point for India’s space journey, Prime Minister Narendra Modi took an out-of-box decision to “unlock” India’s Space sector, marking a proactive shift in government policies. He credited the enabling environment created by the Modi government, which had thrown open the gates of Sriharikota for the public and opened up the space sector for private sector participation, bringing in Foreign Direct Investment (FDI).

    Union Minister Dr. Jitendra Singh addressing at the “Business Conclave” organized by the Times Network in New Delhi.

    This strategic approach, initiated with the personal intervention of PM Narendra Modi, is creating synergy between the government and non-government sectors through frameworks such as the NewSpace India Limited (NSIL) and In-SPACe, boosting innovation and opportunities across the space industry. He added that first Generation space Startups have become successful enterprises.

    Dr. Jitendra Singh also spoke about the historic milestones of the Indian Space Research Organization (ISRO), such as becoming the first nation to successfully reach the South Pole of the Moon.

    While ISRO’s journey began when other nations had already sent humans to the moon, Dr. Jitendra Singh highlighted how India is now leading the way in space exploration with cost-effective and indigenous technologies. Citing the Chandrayaan mission, which was executed at just ₹600 crore—half the cost of similar missions by other countries—he emphasized India’s rise as a global leader in space, science and technology.

    The Minister underscored the transformative impact of space technology on various sectors. He drew attention to the Swamitva Scheme, which uses satellite mapping and drone technology for land record mapping, eliminating the reliance on revenue officials.

    Dr. Jitendra Singh also discussed ISRO’s role in improving communication and connectivity, reinforcing India’s self-reliance in space and satellite technology, and highlighted that 433 foreign satellites had been launched by ISRO which earned 292 million Euros and 172 million $.

    Dr. Jitendra Singh highlighted India’s efforts to foster an inclusive space ecosystem, with women playing a central role in key space projects like Chandrayaan and Aditya L1. He also spoke about India’s growing prominence on the global stage, citing recent developments such as the US’s invitation to send an Indian astronaut to the International Space Station and other future collaborations between India and international space agencies.

    The Minister also pointed to India’s untapped potential in its Himalayan, coastal, and marine resources, which are expected to drive further economic growth and innovation in the coming years. He emphasized how the space sector will play a key role in unlocking these resources for the benefit of the nation.

    Dr. Singh also discussed the growing StartUp ecosystem in India, with Jammu & Kashmir emerging as a role model in agri-tech startups. He highlighted the success of the Aroma Mission: Purple Revolution, which featured in Prime Minister Narendra Modi’s “Mann Ki Baat” and showcased at the Republic Day Parade, empowering the youth in the region. The record number of tourists visiting Jammu and Kashmir each season serves as a testament to the region’s growing development and peace.

    In closing, Dr Jitendra Singh affirmed that India is committed to leading the global space race with entirely indigenously developed technologies that are cost-effective, futuristic, and designed for sustainable growth. He concluded by reiterating that India’s space sector will not only follow the global path but will also carve out its own leadership role on the world stage, marking a new era in space exploration.

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  • MIL-OSI Asia-Pac: English rendering of PM’s speech at inauguration of Advantage Assam 2.0 Investment & Infrastructure Summit 2025 in Guwahati

    Source: Government of India

    Posted On: 25 FEB 2025 2:06PM by PIB Delhi

    Governor of Assam, Shri Lakshman Prasad Acharya ji, dynamic Chief Minister Himanta Biswa Sarma ji, industry leaders, distinguished guests, ladies and gentlemen!

    The land of Eastern India and the Northeast is about to embark on a new future today. Advantage Assam is a grand initiative to connect the entire world with Assam’s potential and progress. History bears witness that Eastern India played a significant role in Bharat’s prosperity in the past. Today, as Bharat moves towards becoming a developed nation, Eastern India and our Northeast are once again set to showcase their strength. I see Advantage Assam as a reflection of this very spirit. I extend my heartfelt congratulations to the Assam government and the entire team of Himanta ji for organising this grand event. I recall when I was visiting Assam for an election campaign in 2013, I spontaneously said something at a gathering— “The day is not far when people, while learning the alphabet, will say: A for Assam.”

    Friends,

    Today, we are all closely observing and understanding global circumstances. Even amidst this global uncertainty, experts around the world have one certainty—and that certainty is Bharat’s rapid growth. There is a solid reason behind this confidence in Bharat. The Bharat of today is taking one step after another, working on a large scale, keeping in mind a long-term vision for the next 25 years of this 21st century. The world’s confidence today rests on Bharat’s young population, which is rapidly becoming skilled and driving innovation. The world trusts Bharat’s neo-middle class, which is emerging from poverty and advancing with new aspirations. The world believes in Bharat’s 1.4 billion people, who support political stability and policy continuity. The world has faith in Bharat’s governance, which is continuously implementing reforms. Today, Bharat is strengthening its local supply chains. Bharat is signing free trade agreements with different regions across the world. Our connectivity with East Asia is continuously improving. Additionally, the new India-Middle East-Europe Economic Corridor is opening up many new opportunities.

    Friends,

    Amidst the growing global trust in Bharat, we have all gathered here today in Assam, on the sacred land of Maa Kamakhya. Assam’s contribution to Bharat’s growth is steadily increasing. The first edition of the Advantage Assam Summit was held in 2018. Back then, Assam’s economy was worth 2.75 lakh crore rupees. Today, Assam has become a 6 lakh crore rupee economy. This means that in just six years under the BJP government, Assam’s economy has doubled in value. This is the double effect of the double-engine government. The large-scale investments in Assam, including those made by all of you, have transformed Assam into a state of unlimited possibilities. The Assam government is focusing on education, skill development, various infrastructure projects, and creating a better investment environment. 

    In recent years, the BJP government has worked extensively on connectivity-related infrastructure in the state. Let me give you an example. Before 2014, there were only three bridges over the Brahmaputra River, meaning that just three bridges were built in 70 years. However, in the past 10 years, we have constructed four new bridges. One of these bridges has been named after Bharat Ratna Bhupen Hazarika ji. Between 2009 and 2014, Assam received an average of 2,100 crore rupees in the railway budget. Our government has increased Assam’s railway budget more than four times, taking it to 10,000 crore rupees. Additionally, over 60 railway stations in Assam are being modernised. Today, the first semi-high-speed train of the Northeast has started running between Guwahati and New Jalpaiguri.

    Friends,

    Assam’s air connectivity is expanding rapidly. Until 2014, flights operated on only seven routes here. Today, flights are running on nearly 30 routes. This has provided a major boost to the local economy and created employment opportunities for the youth of Assam.

    Friends,

    This transformation is not limited to just infrastructure. There has been an unprecedented improvement in law and order. Over the past decade, numerous peace accords have been signed, and long-pending border issues have been resolved. Today, every region, every citizen, and every young person in Assam is working tirelessly for the development of this state.

    Friends,

    Today, major reforms are taking place across every sector and every level of Bharat’s economy. We have consistently worked to improve the Ease of Doing Business. We have built a complete ecosystem to promote industry and an innovation culture. Whether it is policies for start-ups, PLI schemes for manufacturing, or tax exemptions for manufacturing companies and MSMEs, we have formulated excellent policies for all. The government is also making massive investments in infrastructure. This combination of institutional reforms, industry, infrastructure, and innovation is the foundation of Bharat’s progress. That is why investors are recognizing Bharat’s potential and the transformative possibilities of growth. Assam, too, is moving forward at double-engine speed in this progress. Assam has set a target to grow its economy to 150 billion dollars by 2030. I firmly believe that Assam can achieve this goal. My confidence stems from the capable and talented people of Assam and the commitment of the BJP government here. Today, Assam is emerging as the gateway between Southeast Asia and Bharat. To further enhance this potential, the government has launched the North East Transformative Industrialisation Scheme, also known as “Unnati”. This scheme will boost industry, investment, and tourism across the Northeast, including Assam. I urge all industry leaders here to take full advantage of this scheme and Assam’s unlimited potential. Assam’s natural resources and strategic location make it a preferred investment destination. One example of Assam’s strength is Assam Tea. Assam Tea is a global brand, a cherished part of tea lovers’ lives worldwide. Assam Tea has now completed 200 years. This legacy inspires Assam to excel in other sectors as well.

    Friends,

    Today, a major transformation is taking place in the global economy. The world is demanding a resilient supply chain. At this crucial time, Bharat has launched an initiative to strengthen its manufacturing sector in mission mode. Under Make in India, we are promoting low-cost manufacturing. Our industries—pharmaceuticals, electronics, and automobiles—are not only meeting domestic demand but are also setting new benchmarks of manufacturing excellence in international markets. Assam is playing a crucial role in this manufacturing revolution.

    Friends,

    Assam has always had a significant share in global trade. Today, Assam accounts for more than 50% of Bharat’s onshore natural gas production. In the past few years, the capacity of Assam’s refineries has increased significantly. Assam is also emerging rapidly in new-age sectors such as electronics, semiconductors, and green energy. Due to the government’s policies, Assam is becoming a hub for high-tech industries as well as start-ups.

    Friends,

    Just a few days ago, the central government approved the Namrup-IV plant in the Union Budget. In the coming years, this urea production plant will meet the fertilizer demand of not just the Northeast but the entire country. The day is not far when Assam will become a major manufacturing hub of Eastern India. The central government is fully supporting the BJP-led state government in achieving this goal.

    Friends,

    In the 21st century, the world’s progress depends on digital revolution, innovation, and technological advancements. The better we prepare for this, the stronger we will be on the global stage. That’s why our government is moving forward at full speed with 21st-century policies and strategies. We all know how Bharat has made a huge leap in electronics and mobile manufacturing over the past 10 years. Now, Bharat aims to replicate this success story in semiconductor production as well. I am proud that Assam is emerging as a key centre for semiconductor manufacturing in Bharat. A few months ago, the Tata Semiconductor Assembly & Test Facility was inaugurated in Jagiroad, Assam. This plant will play a crucial role in promoting technological growth across the entire Northeast region in the coming years.

    Friends,

    We have also collaborated with IITs to drive innovation in the semiconductor sector. A semiconductor research centre is also being developed in the country. By the end of this decade, the electronics sector is expected to reach a value of 500 billion dollars. Given our speed and scale, it is certain that Bharat will emerge as a global powerhouse in semiconductor production. This will create millions of jobs and significantly benefit Assam’s economy.

    Friends,

    Over the past 10 years, Bharat has taken policy decisions while being mindful of its environmental responsibilities. The world today considers our Renewable Energy Mission a model practice and is following our approach. The country has made massive investments in solar, wind, and sustainable energy resources in the last 10 years. This has not only fulfilled our ecological commitments but has also significantly expanded our renewable energy production capacity. We have set a target to add 500 GW of renewable energy capacity to the country’s energy infrastructure by 2030. The government is also working on a mission to achieve an annual production of 5 million metric tons of green hydrogen by 2030. With the expansion of gas infrastructure, demand for gas in the country has also risen rapidly. The gas-based economy is expanding at a fast pace, and Assam holds a huge advantage in this journey. The government has created numerous opportunities for industries—from PLI schemes to green initiatives, all policies have been designed in your favour. I want Assam to emerge as a leader in the renewable energy sector. However, this can only happen when industry leaders like you step forward and maximise Assam’s full potential.

    Friends,

    By 2047, Eastern India will play a crucial role in making Bharat a ‘Viksit Bharat’ (Developed India). Today, the Northeast and Eastern India are advancing rapidly in infrastructure, logistics, agriculture, tourism, and industry. The day is not far when the world will witness this region leading the way in Bharat’s development journey. I firmly believe that you will be partners in this journey and will contribute to Assam’s growth. Let us work together to make Assam a state that takes Bharat’s capabilities to new heights in the entire Global South. Once again, I extend my best wishes to all of you for this summit. And as I say this, I give you my assurance—I stand with you and fully support your contributions in the ‘Viksit Bharat’ journey.

    Thank you very much.

     

    DISCLAIMER: This is the approximate translation of PM’s speech. Original speech was delivered

    MIL OSI Asia Pacific News

  • MIL-OSI Banking: Verizon Business launches turnkey IoT solution with Atlanta Hawks as first customer

    Source: Verizon

    Headline: Verizon Business launches turnkey IoT solution with Atlanta Hawks as first customer

    What you need to know:

    • Verizon Sensor Insights, a turnkey IoT solution that has been sold to companies in diverse industries such as food refrigeration and insurance, is being deployed by the Atlanta Hawks at State Farm Arena to monitor and manage the temperature and condition of sensitive technical equipment and to better track waste disposal and resource efficiency.
    • Sensor Insights is part of a larger technology initiative with Verizon to enhance stadium operations at State Farm Arena.
    • The solution includes pre-approved sensors, Verizon-certified gateways, cellular connectivity, and a central management portal.

    NEW YORK — Verizon Business today announced the Atlanta Hawks and State Farm Arena as the marquee launch partner for Verizon Sensor Insights, an innovative solution that allows for the management and scaling of complex Internet of Things (IoT) infrastructure. Installed in the arena’s technical equipment hub, Verizon Sensor Insights provides near real-time data-driven intelligence to ensure all technical equipment is operating at peak efficiency.

    Sensor Insights is designed to be turnkey and convenient for businesses of any size, including small and medium businesses, and has also been sold to companies in food refrigeration and insurance. Suitable for nearly any industry, the solution includes pre-approved sensors, Verizon-certified gateways, cellular connectivity, and a central management portal, all atop the foundational Verizon ThingSpace IoT platform.

    “State Farm Arena is constantly looking for ways to push the boundaries of innovation and improve the experience for our fans and staff,” said Kim Rometo, Chief Technology & Innovations Officer for the Atlanta Hawks & State Farm Arena. “By implementing Verizon Sensor Insights, multiple stakeholders can proactively monitor and manage critical operational aspects, ensuring a more seamless and efficient experience for everyone.”

    Organizations across commercial sectors are embracing IoT to improve energy efficiency, streamline maintenance operations, and enhance their overall sustainability efforts. Sensor Insights allows customers to activate, onboard, and manage sensors and gateways, and manage cellular and IoT connections across multiple IoT protocols including LoRaWAN, BLE (Bluetooth Low Energy) — all from an easy-to-use central web portal. Users gain near real-time alerts and trend analysis for optimized operational decision-making.

    By deploying Sensor Insights to manage their network of IoT-enabled sensors at State Farm Arena, the Atlanta Hawks are already gaining actionable insights into the technology equipment health and IDF room environment to better predict maintenance needs and create a smarter and more efficient arena, with plans to expand into new use cases in the coming months.

    “We are thrilled to have the Atlanta Hawks and State Farm Arena as an early adopter of Verizon Sensor Insights,” said Scott Lawrence, Chief Product Officer, Verizon Business. “This deployment is a great example of how high-performing organizations use IoT and other connected technology to improve efficiency and enhance business operations.”

    As part of a larger technology partnership with Verizon, State Farm Arena has also installed Delta Fly-Through Lanes powered by Verizon at Gates 1, 2, 3, and 7, and a new Hawks Express Cashierless Checkout store, powered by Verizon’s 5G Edge technology and developed in collaboration with spatial intelligence and autonomous retail solutions provider AiFi.

    Located on the 100 West main concourse and operational today, the Hawks Express store uses AI-powered computer vision technology to make it simple, fast and convenient for fans to purchase food and beverages in the arena without waiting in line. Customers simply enter the store, select their items, and exit—with purchases automatically processed through their mobile payment method.

    The Delta Fly-Through Lanes lanes at State Farm Arena were designed to streamline the fan ticketing and entry experience. Underpinned by Wicket’s facial authentication technology, Verizon’s 5G Edge Accelerated Access solution for stadiums and venues enhances security while reducing wait times to ensure members are able to spend less time at the entrance and more time enjoying the game. Since becoming operational in October of 2024, these Delta Fly-Through Lanes have expedited the ticket scanning process for Atlanta Hawks members, showing 2,000 enrollments, approaching 10,000 tickets scanned with an average ticket redemption time of 6 seconds, and 72% of members are repeat users.

    Learn more on our Verizon Sensor Insights product page and contact your Verizon Business sales representative to begin a trial today.

    MIL OSI Global Banks

  • MIL-OSI Europe: Isabel Schnabel: No longer convenient? Safe asset abundance and r*

    Source: European Central Bank

    Keynote speech by Isabel Schnabel, Member of the Executive Board of the ECB, at the Bank of England’s 2025 BEAR Conference

    London, 25 February 2025

    Over the past few years, global bond investors have fundamentally reappraised the expected future course of monetary policy.

    Even as inflation has receded and policy restriction has been dialled back, current market prices suggest that maintaining price stability will require higher real interest rates in the future than before the pandemic.

    In my remarks today, I will argue that the shift in market expectations about the level of r* – the rate to which the economy is expected to converge in the long run once current shocks have run their course – is consistent with two sets of observations.

    The first is that the era during which risks to inflation have persistently been to the downside is likely to have come to an end.

    Growing geopolitical fragmentation, climate change and labour scarcity pose measurable upside risks to inflation over the medium to long term. This is especially true as the recent inflation surge may have permanently scarred consumers’ inflation expectations and may have lowered the bar for firms to pass through adverse cost-push shocks to consumer prices.

    The second observation is that we are transitioning from a global “savings glut” towards a global “bond glut”.

    Persistently large fiscal deficits and central bank balance sheet normalisation are gradually reducing the safety and liquidity premia that investors have long been willing to pay to hold scarce government bonds. The fall in the “convenience yield”, in turn, reverses a key factor that had contributed to the decline in real long-term interest rates, and hence r*, during the 2010s.

    The implications for monetary policy are threefold.

    First, a higher r* calls for careful monitoring of when monetary policy ceases to be restrictive. Second, central bank balance sheet policies may themselves affect the level of r* through the convenience yield, making them potentially less effective than previously thought. Third, because central bank reserves also offer convenience services to banks, it is optimal to provide reserves elastically on demand as quantitative tightening reduces excess liquidity.

    Upward shift in r* signals lasting change in the inflation regime

    Starting in 2021, long-term government bond yields rose measurably across advanced economies. Today, the ten-year yield of a German government bond is about two and a half percentage points higher than in late 2021 (Slide 2, left-hand side).

    What is remarkable about the rise in nominal bond yields in the euro area over this period is that it was not driven by a change in inflation compensation. Investors’ views about future inflation prospects are broadly the same today as they were three years ago (Slide 2, right-hand side).

    Rather, nominal interest rates rose because real interest rates increased. Euro area real long-term rates are now trading at a level that is substantially higher than the level prevailing during most of the post-2008 global financial crisis period (Slide 3, left-hand side).

    Part of the rise in real long-term interest rates is a mechanical response to the tightening of monetary policy.

    Long-term interest rates are an average of expected short-term interest rates over the lifetime of the bond, plus a term premium. So, when we raised our key policy rates in response to the surge in inflation, the average real rate expected to prevail over the next ten years increased.[1]

    What is more striking, however, is that investors also fundamentally revised the real short-term rate expected to prevail once inflation has sustainably returned to our target. This rate is typically taken as a proxy for the natural rate of interest, or r*.

    The real one-year rate expected in four years (1y4y), for example, is now at the highest level since the sovereign debt crisis (Slide 3, right-hand side). Even at very distant horizons, such as in nine years, the expected real short-term rate (1y9y) has increased measurably in recent years.

    To a significant extent, these developments reflect a genuine reappraisal of the real equilibrium interest rate that is consistent with our 2% inflation target. A rise in the term premium, which is the excess return investors demand for the uncertainty surrounding the future interest rate path, can explain less than half of the change in the real 1y4y rate.[2]

    These forward rates have also remained surprisingly stable since 2023, with a standard deviation of around just 15 basis points, despite the measurable decline in inflation, the protracted weakness in aggregate demand and the series of structural headwinds facing the euro area.

    We are seeing a similar upward shift in model-based estimates of r*. According to estimates by ECB economists, the natural rate of interest in the euro area has increased appreciably over the past two years, and even more so than what market-based real forward rates would suggest (Slide 4).[3]

    This result is robust across many models and even holds when accounting for the significant uncertainty surrounding these estimates. In other words, for drawing conclusions about the directional change of r* from the rise in market and model-based measures, the actual rate level is largely irrelevant.

    What matters is the direction of travel. And that is unambiguous: we are unlikely to return to the pre-pandemic macroeconomic environment in which central banks had to bring real rates into deeply negative territory to deliver on their price stability mandate. This suggests that the nature of the inflation process is likely to have changed lastingly.

    Real interest rates are only loosely tied to trend growth

    Why do markets expect such a trend reversal for real interest rates in the euro area?

    One answer is that some of the forces that weighed on inflation during the 2010s are now reversing.

    Globalisation is a case in point. The integration of China and other emerging market economies into the global production network and the broad-based decline in tariff and non-tariff barriers were important factors reducing price pressures in advanced economies over several decades.[4]

    Today, protectionist policies, the weaponisation of critical raw materials and geopolitical fragmentation are increasingly dismantling the foundations on which trade improved the welfare of consumers worldwide.

    These forces can be expected to have first-order effects on inflation.

    European gas prices, for example, are up by 65% compared with a year ago despite the significant decline over recent days. Oil prices, too, have increased since September of last year, in part reflecting the marked depreciation of the euro.

    While commodity prices are inherently volatile, and may reverse quickly, other deglobalisation factors, such as reshoring and the lengthening of supply chains, are likely to increase price pressures more lastingly.

    And yet, the persistent rise in real forward rates poses a conundrum in the euro area.

    The reason is that increases in long-term real interest rates are typically thought of as being associated with improvements on the supply side of the economy, such as productivity growth, the labour force and the capital stock.

    At present, however, these factors do not point towards an increase in r* in the euro area.

    Potential growth has generally been revised lower, not higher, as many of the factors currently holding back consumption and especially investment are likely to be structural in nature, such as a rapidly ageing population and deteriorating competitiveness.

    The weak link between the structural factors driving potential growth and r* is, however, not exceptional from a historical perspective.

    Indeed, over time there has been little evidence of a stable relationship between real interest rates and drivers of potential growth, such as demographics and productivity.[5] They have had the expected relationship in some subsamples but not in others.[6]

    Similarly, in the most popular framework for estimating r*, the seminal model by Laubach and Williams, potential growth has played an increasingly subordinated role in explaining why the natural rate of interest has remained at a depressed level in the United States following the global financial crisis (Slide 5, left-hand side).[7]

    Rather, the persistence in the decline in r* is explained to a large extent by a residual factor, which lacks economic interpretation.

    Moreover, if growth was the main driver of r*, then one would expect all real rates in the economy to adjust in a similar way. But while real rates on safe assets have declined since the early 1990s, the return on private capital has remained relatively constant.[8]

    Decline in the convenience yield is pushing r* up

    A growing body of research attempts to reconcile these puzzles. Many studies attribute a significant role to the money-like convenience services that safe and liquid assets, such as government bonds, provide to market participants.

    The yield that investors are willing to forgo in equilibrium for these services is what economists call the “convenience yield”.[9]

    This yield, in turn, critically depends on the net supply of safe assets: When these are scarce, investors are willing to pay a premium to hold them, depressing the real equilibrium rate of interest. And when they are abundant, the premium falls, putting upward pressure on r*.

    New research by economists at the Board of Governors of the Federal Reserve System shows how incorporating the convenience yield into the Laubach and Williams framework significantly improves the explanatory power of the model.[10]

    In fact, the convenience yield can explain most of the residual factor and is estimated to have caused a large part of the secular decline in the real natural rate in the United States (Slide 5, right-hand side).

    Liquidity requirements that regulators imposed on banks in the wake of the global financial crisis, the Federal Reserve’s balance sheet policies and the integration of many large emerging market economies into the global economy have led to an unprecedented increase in the demand for safe and liquid assets, driving up their convenience yield.[11]

    These findings are in line with earlier research showing that the convenience yield has played an equally important role in depressing the real equilibrium rate in many other advanced economies, including the euro area, during the 2010s.[12]

    This process is now reversing. According to the work by the Federal Reserve economists, r* has recently increased visibly, contrary to what the model without a convenience yield would suggest.

    Asset swap spreads are a good indicator of the convenience yield. Both interest rate swaps and government bonds are essentially risk-free assets, so they should in principle yield the same return.

    For a long time, this has been the case: before the start of quantitative easing (QE) in the euro area in 2015, the spread between a ten-year German Bund and a swap of equivalent maturity was close to zero on average (Slide 6, left-hand side).

    Over time, however, with the start of QE and the parallel fiscal consolidation by governments reducing the net supply of government bonds in the market, the premium that investors were willing to pay to secure their convenience services rose measurably. At the peak, ten-year Bunds were trading nearly 80 basis points below swap rates.

    But since about mid-2022 the asset swap spread has persistently narrowed. In October of last year it turned positive for the first time in ten years, and it now stands close to the pre-QE average again.

    Other measures of the convenience yield paint a similar picture. The spread between ten-year bonds issued by the Kreditanstalt für Wiederaufbau (KfW) and German Bunds has narrowed from about
    -80 basis points in October 2022 to just -30 basis points today (Slide 6, right-hand side).[13]

    Furthermore, in the repo market, we have observed a steady and measurable rise in overnight rates and a convergence across collateral classes (Slide 7, left-hand side).[14]

    Over the past few years, transactions secured by German government collateral, in particular, were trading at a significant premium over others. This premium has declined considerably, reflecting a reduction in collateral scarcity.

    Finally, in the United States, the spread between AAA corporate bonds and US Treasuries has declined from almost 100 basis points in 2022 to 40 basis points today (Slide 7, right-hand side). It currently stands close to its historical low.

    Global savings glut has turned into a global bond glut

    All this suggests that, today, market participants value the liquidity and safety services of government bonds less than they did in the past, as the net supply of government bonds has increased and continues to increase at a notable pace.

    In Germany and the United States, for example, the sovereign bond free float as a share of the outstanding volume has increased by more than ten percentage points over the past three years (Slide 8, left-hand side). It is projected to steadily increase further in the coming years.

    So, the global savings glut appears to have turned into a global bond glut, which reduces the marginal benefit of holding government bonds.

    There are several factors contributing to the rise in the bond free float.[15]

    First, and most importantly, net borrowing by governments remains substantial. The public deficit is estimated to have been around 5% of GDP across advanced economies last year, and it is expected to decline only marginally in the coming years (Slide 8, right-hand side).

    Second, rising geopolitical fragmentation is likely to be contributing to a drop in demand for government bonds in some parts of the world.

    In the United States, for example, there has been a marked decline in the share of foreign official holdings of US Treasury securities since the global financial crisis (Slide 9, left-hand side). It is now at its lowest level in more than 20 years.[16] The US Administration’s attempt to reduce the current account deficit is bound to further depress foreign holdings of US Treasuries.

    Third, central banks are in the process of normalising their balance sheets (Slide 9, right-hand side). Unlike when central banks announced large-scale asset purchases, the effects of quantitative tightening (QT) on yields are likely to materialise only over time, as many central banks take a gradual approach when reducing the size of their balance sheets.

    Higher r* calls for cautious approach to rate easing

    These developments have three important implications for monetary policy.

    One is that central banks are dialling back policy restriction in an environment in which structural factors are putting upward pressure on the real equilibrium rate. Recent analysis by the International Monetary Fund (IMF), for example, suggests that a fall in the convenience yield to pre-2000 average levels could raise natural rates by about 70 basis points.[17]

    While a significant part of these effects may have already materialised, other factors could push real rates up further over the medium term. The IMF projects that, in the coming years, overall global investment – public and private – will reach the highest share of GDP since the 1980s, also reflecting borrowing needs associated with the digital and green transitions as well as defence spending.

    Recent global initiatives aimed at boosting the development and use of artificial intelligence underscore these projections. Overall, these forces may well be larger than those that continue to weigh on the real equilibrium rate, such as an ageing population.

    Central banks, therefore, need to proceed cautiously. We do not fully understand how the pervasive changes to our economies are affecting the steady state, or what the path to the new steady state will look like.

    In this environment, the most appropriate way to conduct monetary policy is to look at the incoming data to assess how fast, and to what extent, changes to our key policy rates are being transmitted to the economy.

    For the euro area, this assessment suggests that, over the past year, the degree of policy restraint has declined appreciably – to a point where we can no longer say with confidence that our policy is restrictive.

    According to the most recent bank lending survey, for example, 90% of banks say that the general level of interest rates has no impact on the demand for corporate loans, with 8% saying that it contributes to boosting credit demand (Slide 10, left-hand side). This is a marked shift from a year ago when a third of all banks reported that interest rates were weighing on credit demand.

    For mortgages, the evidence is even more striking. Today almost half of the banks report that the level of interest rates supports loan demand, while a year ago more than 40% said the opposite. As a result, a net 42% of banks report an increase in the demand for mortgages, close to the historical high.

    Survey evidence is gradually showing up in actual lending data. Credit to firms expanded by 1.5% in December, the highest rate in a year and a half, and credit to households for house purchases grew by 1.1% (Slide 10, right-hand side).

    Strong bank balance sheets are contributing to the recovery and, given the lags in policy transmission, further easing is still in the pipeline.

    Lending conditions are also relatively favourable from the perspective of borrowers. The spread between the composite cost of borrowing for households and sovereign bond yields is well below the level seen over most of the 2010s and is now close to the historical average (Slide 11).[18]

    And while some maturing loans from the period of very low interest rates will still need to be refinanced at higher rates, over time this debt has declined in real terms and interest payments as a fraction of net income are buffered by rising nominal wages.

    Overall, therefore, it is becoming increasingly unlikely that current financing conditions are materially holding back consumption and investment. The fact that growth remains subdued cannot and should not be taken as evidence that policy is restrictive.

    As the ECB’s most recent corporate telephone survey suggests, the continued weakness in manufacturing is increasingly viewed by firms as structural, reflecting a combination of high energy and labour costs, an overly inhibitive and uncertain regulatory environment and increased import competition, especially from China.[19]

    Such structural headwinds reduce the economy’s sensitivity to changes in monetary policy.

    QE’s impact on r* is reducing its effectiveness

    The second implication from the impact of the convenience yield on r* is related to the use of balance sheet policies.

    If QE raises the convenience yield by reducing the net supply of government bonds, it may ultimately lower the real equilibrium interest rate. Importantly, this channel – the convenience yield channel – is distinct from the term premium channel.[20]

    So, doing QE could be like chasing a moving target.

    It reduces long-run rates by compressing the term premium.[21] But by making investors willing to pay a higher safety premium when the supply of safe assets shrinks, it may also reduce the interest rate level below which monetary policy stimulates growth and inflation.

    This can also be seen by looking at how QE changes the balance of savings and investments. Fiscal deficits absorb private savings and thereby increase r*. By doing QE, central banks absorb fiscal deficits and thereby lower r*.

    In other words, central bank balance sheet policies may be less effective than previously thought.[22] This could be an additional factor explaining why large-scale asset purchases did not succeed in bringing inflation back to 2% before the pandemic.

    Of course, the same logic holds true when central banks reduce their balance sheets.

    If QE contributed to depressing r*, QT will raise it. Any rise in real rates may then be less consequential for growth and inflation. It would then be misguided to compensate for higher long-term interest rates resulting from QT with lower short-term rates.

    This is indeed what recent research suggests: QT announcements tend to cause a significant decline in the convenience yield of safe assets.[23]

    There is one caveat, however.

    QE and QT are implemented by issuing and absorbing central bank reserves, which themselves are safe assets – in fact, reserves are the economy’s ultimate safe asset because they are free of liquidity and interest rate risk.[24]

    Banks therefore highly value the convenience services of central bank reserves. So, when evaluating the effects of central bank balance sheet policies on r*, it is necessary to consider both the asset and liability side.

    Research by economists from the Bank of England does exactly that.[25] They show that the effects of QT on the real equilibrium rate depend on the relative strength of two factors.

    One is the effect on the bond convenience yield, which causes r* to rise as the supply of government bonds increases.

    The other is the effect on the convenience yield of reserves. That effect is highly non-linear: when reserves are scarce, banks are willing to pay a high mark-up on wholesale interest rates, as was evident in the United States in 2019 when repo rates surged strongly.

    So, if QT leads to a scarcity of reserves, it may cause the overall convenience yield to rise, and hence equilibrium rates to fall.

    Convenience of reserves and the ECB’s operational framework

    At the ECB, we took this factor into account when we reviewed our operational framework last year.[26] This is the third implication for monetary policy.

    The new framework allows banks to demand as many reserves as they find optimal at a spread that is 15 basis points above the rate which the ECB pays to banks when they deposit their excess reserves with us. So, the opportunity cost of holding reserves is comparatively small, given the convenience services reserves provide to banks.

    In addition, our framework allows banks themselves to generate an increase in safe assets – by pledging non-high quality liquid assets (non-HQLA) in our lending operations. In doing so, banks on average generate € 0.92 of net HQLA for every euro that they borrow from the Eurosystem.[27]

    Our framework therefore recognises that years of crises, more stringent regulatory requirements and the advance of new technologies – some of which increase the risk of “digital” bank runs – imply that banks may wish to hold larger liquidity buffers than they historically have done.

    Supplying central bank reserves elastically will ensure that reserves will not become scarce as balance sheet normalisation proceeds. And if banks access our standard refinancing operations when they are in need of liquidity, they will also not have to adjust their lending activities in response to the decline in reserves, as is sometimes feared.[28]

    For now, the recourse to our lending operations has been limited, as there is still ample excess liquidity. But as we transition over the coming years to a world in which reserves are less abundant, banks will increasingly start borrowing reserves via our operations.

    Three ideas could be explored to make this transition as smooth as possible.

    First, regular testing requirements in the counterparty framework could help ensure operational readiness while also allowing counterparties to become more comfortable with participating in our operations. A lack of operational readiness was one of the factors contributing to the March 2023 turmoil in the United States.[29]

    Second, and related, obtaining central bank funding requires thorough collateral management, especially if the collateral framework is as broad as the Eurosystem’s. For non-HQLA collateral, in particular, the pricing and due diligence process can be operationally complex and time-consuming.

    For this reason, central banks sometimes require counterparties to pre-position collateral to ensure that funding can be readily obtained.[30] In the euro area, some banks already pre-position collateral voluntarily, in particular non-marketable collateral which cannot be used in private repo markets (Slide 12, left-hand side).

    Banks could be further encouraged to mobilise with the central bank the collateral that is eligible but currently stays idle on their balance sheets. This would increase operational readiness, mitigate financial stability risks and reduce precautionary reserve demand as banks would have higher certainty that they can access central bank liquidity at short notice.

    In the Eurosystem, given its broad collateral framework, such an approach may be more effective in helping banks adapt their liquidity management to the characteristics of a demand-driven operational framework compared with a blanket requirement to pre-position collateral.

    Finally, in some jurisdictions central bank operations are fully integrated into the platforms commonly used by banks to operate in private repo markets.

    This offers banks a number of advantages, including seamless access to transactions with the market and with the central bank, and – depending on the design of clearing arrangements and accounting rules – it could potentially allow banks to net out their positions, thereby freeing up valuable balance sheet space.

    Offering banks the possibility to access Eurosystem refinancing operations through a centrally cleared infrastructure could contribute to making our operations more economical in an environment in which dealer balance sheets are increasingly constrained (Slide 12, right-hand side).[31]

    The design of such arrangements should preserve equal treatment across our diverse range of counterparties, regardless of their size, jurisdiction and business model, maintain the possibility to mobilise a broad range of collateral and be compatible with our risk control framework.

    Further reflection is needed on these considerations, including a comprehensive assessment of the benefits and costs.

    Conclusion

    Let me conclude.

    The shocks experienced since the pandemic led to an abrupt end of the secular downward trend in real interest rates. Whether this will be merely an interlude, or the beginning of a new era, is inherently difficult to predict.

    But looking at the ongoing transformational shifts in the balance of global savings and investments, as well as at the fundamental challenges facing our societies today, higher real interest rates seem to be the most likely scenario for the future.

    This has implications for our monetary policy. Central banks will need to adjust to the new environment, both to secure price stability over the medium term and to implement monetary policy efficiently.

    Thank you.

    MIL OSI Europe News

  • MIL-OSI Europe: Answer to a written question – Delays in the payment of compensatory fees from hydroelectric projects in Greece – E-000149/2025(ASW)

    Source: European Parliament

    The Commission takes note of the information provided on the situation in Greece. The imposition of compensatory (reciprocal) fees could be one way to consider the needs of local population and share the benefits of the green transition .

    Moreover, Article 15d (2) of the revised Renewable Energy Directive[1], with transposition deadline on 21 May 2025, obliges Member States to adopt measures to promote public acceptance of renewable energy projects by means of direct and indirect participation of local communities in those projects.

    The application of compensatory (reciprocal) fees, depends on the specific rules in the relevant national legislation. Non or incorrect application of national legislation must be brought up and decided before national courts.

    Given the need to adjust to national and local circumstances, a ‘one size fits all’ solution has not been identified in this area.

    The Commission will continue to promote the exchange of best practices among Member States, including via the upcoming Citizens Energy Package and engagement in regional high-level groups[2].

    • [1] Directive (EU) 2023/2413 of the European Parliament and of the Council of 18 October 2023 amending Directive (EU) 2018/2001, Regulation (EU) 2018/1999 and Directive 98/70/EC as regards the promotion of energy from renewable sources, and repealing Council Directive (EU) 2015/652 (OJ L, 2023/24, 31.10.2023, ELI: http://data.europa.eu/eli/dir/2023/2413/oj).
    • [2] https://energy.ec.europa.eu/topics/infrastructure/high-level-groups_en
    Last updated: 25 February 2025

    MIL OSI Europe News

  • MIL-OSI Europe: Answer to a written question – Decarbonisation investments in the steel sector – E-002694/2024(ASW)

    Source: European Parliament

    The hydrogen and decarbonised gas market package[1] sets a clear framework for the development of infrastructure and the revised Renewable Energy Directive[2] creates obligations for the consumption of renewable hydrogen in industry and transport. When transposing them, Member States should put in place incentives for the sectors.

    In 2023, the Commission identified 65 European priority hydrogen infrastructure projects[3], that can benefit from funding under the Connecting Europe Facility and accelerated permitting. The Commission launched the second European Hydrogen Bank auction on 3 December 2024[4], next to Innovation Fund calls[5].

    In line with Article 30 (2) of Regulation (EU) 2023/956, the Commission will in 2025 assess a potential scope extension of the Carbon Border Adjustment Mechanism (CBAM).

    This includes an assessment of goods further down the value chain, goods at risk of carbon leakage other than those listed in Annex I of the CBAM Regulation and other input materials.

    On this basis, the Commission will prepare, where appropriate, a legislative proposal, including an impact assessment, on extending the scope of the regulation.

    Member States can prioritise sectors for potential future Important Projects of Common European Interest (IPCEIs). Several approved IPCEIs[6] have benefitted the steel industry’s green transition through renewable hydrogen.

    In addition, the Guidelines for Climate, Environmental Protection and Energy and the Temporary Crisis and Transition Framework allow Member States to notify individual aid measures[7] and aid schemes supporting industrial decarbonisation[8] or renewable hydrogen production or carbon capture and storage.

    • [1] Directive (EU) 2024/1788 and  Regulation (EU) 2024/1789 .
    • [2]  Directive (EU) 2023/2413.
    • [3] Projects of Common Interest and Projects of Mutual Interest, including ~20,000km of pipelines, storages, terminals, and electrolysers: C/2023/7930 final.
    • [4] EUR 1.2 billion of EU funds and up to EUR 836 million from Spain, Lithuania, and Austria for projects in their Member State.
    • [5] Two H2 DRI projects producing and consuming large volumes of H2 have already been awarded under the Innovation Fund, ‘HYBRIT’ (Sweden) https://ec.europa.eu/assets/cinea/project_fiches/innovation_fund/101051316.pdf) and ‘H2Green Steel’ (Sweden) (https://ec.europa.eu/assets/cinea/project_fiches/innovation_fund/101133206.pdf).
    • [6] ‘Hy2Tech’ (https://ec.europa.eu/commission/presscorner/detail/en/ip_22_4544), ‘Hy2Infra’ (https://ec.europa.eu/commission/presscorner/detail/en/ip_24_789) and ‘Hy2Use’ (https://ec.europa.eu/commission/presscorner/detail/en/ip_22_5676).
    • [7] See an example: https://ec.europa.eu/commission/presscorner/detail/en/ip_22_5968
    • [8] For instance a German scheme (https://ec.europa.eu/commission/presscorner/detail/en/ip_24_845) and an Austrian scheme (https://ec.europa.eu/commission/presscorner/detail/en/ip_24_4746).

    MIL OSI Europe News

  • MIL-OSI Security: IAEA Profile: A Woman’s Mission to Advance Nuclear Information Management

    Source: International Atomic Energy Agency – IAEA

    Dibuleng Mohlakwana speaking at the ‘Innovative Technologies for Nuclear Information Management’ side event during the 68th IAEA General Conference in September 2024. (Photo: IAEA)

    The IAEA profiles employees to provide insight into the variety of career paths that support the Agency’s mission of Atoms for Peace and Development and to inspire and encourage readers, particularly women, to pursue careers in STEM (science, technology, engineering and mathematics) or STEM-adjacent fields. Read more profiles of women at the IAEA.   

    Technology is increasingly shaping how we share and retrieve information, and demand for information continues to grow. As a result, information science stands at the forefront of innovation and knowledge sharing.

    “Information is key to driving performance in organizations, just like financial and human resources. Every decision relies on available data and information,” said Dibuleng Mohlakwana, Head of the IAEA Nuclear Information Section. “My mission at the IAEA is to help people make informed decisions and navigate the vast amount of information available today.”

    With nearly 30 years of experience in information, knowledge and records management, Mohlakwana oversees the collection and management of nuclear information accessible to the IAEA and the public. Her role also involves introducing innovative tools and techniques to help the IAEA continuously improve how it shares, organizes and makes information accessible.

    Born in Limpopo Province, South Africa, Mohlakwana grew up in a family of educators and agriculturalists. From a young age, her family instilled in her the value of hard work, resilience and education, as well as the independence to carve her own path. This gave her a strong foundation for pursuing her ambitions.

    “Information science chose me,” Mohlakwana said. “At 17, I was drawn to information science while studying at the University of Limpopo. I realized effective information management is crucial for organizational success, motivating me to ensure that the right information reaches the right people at the right time.” She went on to earn a master’s degree in information and knowledge management and a PhD in information science.

    Mohlakwana began her career as a librarian and credits her network and mentors for shaping her along the way.  Prior to joining the IAEA, she was Director of the eResearch Knowledge Centre in South Africa where she was responsible for research support, library and information services, and the accessibility of research outputs and data via an open access repository.

    As her career progressed, Mohlakwana was motivated by the desire to help address international challenges, particularly energy solutions.

    “As I witnessed the growing energy challenges in South Africa, from aging infrastructure to heavy reliance on coal, and the country’s need for solutions like nuclear power expansion, I realized that both the challenges and the solutions were not just local—but global,” said Mohlakwana. “Joining the IAEA was a chance to be part of something larger, to contribute to the global effort in shaping a more sustainable energy future for all.”

    MIL Security OSI

  • MIL-OSI Security: Minuteman III test launch showcases readiness of U.S. nuclear force’s safe, effective deterrent

    Source: United States Strategic Command

    A joint team of Air Force Global Strike Command Airmen launched an unarmed Minuteman III intercontinental ballistic missile equipped with a single telemetered joint test assembly re-entry vehicle Feb. 19 at 1 a.m. Pacific Time from Vandenberg Space Force Base, California.

    The Western Range at Vandenberg Space Force Base serves as the primary testing ground for the Air Force Global Strike Command’s ICBM deterrent architecture. This test launch is part of routine and periodic activities designed to demonstrate that the United States’ nuclear deterrent remains safe, secure, reliable, and effective in deterring 21st-century threats and reassuring our allies. With over 300 similar tests conducted in the past, this particular test is part of the Nation’s ongoing commitment to maintaining a credible deterrent and is not a response to current world events.

    “Today’s Minuteman III test launch is just one of the ways the Department of the Air Force demonstrates the readiness, precision, and professionalism of U.S. nuclear forces,” said Acting Secretary of the Air Force Gary Ashworth. “It also provides confidence in the lethality and effectiveness of the nation’s nuclear deterrence mission.”

    AFGSC Commander Gen. Thomas Bussiere added, “The nuclear triad is the cornerstone of the national security of our country and allies around the globe.”

    “This test launch is demonstrative of our nation’s ICBM readiness and reliability,” he said. “Because of the skill sets and expertise of our maintenance personnel and our missile crews, our freedoms and the homeland remain secure.”

    Vandenberg’s 377th Test and Evaluation Group, located at Vandenberg SFB, oversaw the test launch. It is the nation’s only dedicated ICBM test organization professionally executing tests that accurately measure the current and future capability of the ICBM force.

    “During this test, we collected and analyzed performance and other key data points to evaluate current missile system competencies,” said Col. Dustin Harmon, 377th TEG commander. “This allows our team to analyze and report accuracy and reliability for the current system while validating projected missile system improvements. The data we collect and analyze is crucial for maintaining Minuteman III while we pave the way for Sentinel.”

    The ICBM’s reentry vehicle traveled approximately 4,200 miles to the U.S. Army Space and Missile Defense Command’s Ronald Reagan Ballistic Missile Defense Test Site located within Republic of the Marshall Islands at the Kwajalein Atoll. Reagan Test Site sensors, including high-fidelity metric and signature radars, as well as optical sensors and telemetry, support the research, development, test and evaluation of America’s defense and space programs. For these tests, RTS team members collect radar, optical and telemetry data in the terminal phase of flight to evaluate system performance.

    “The Reagan Test Site serves as the supporting range for all Glory Trip missions,” said U.S. Army Lt. Col. Casey Rumfelt, RTS range director. “It’s a vital national asset used to support operational and developmental tests of our nation’s offensive and defensive systems. RTS provides a unique suite of instrumentation and an ideal geographic location to meet many of the U.S. testing needs that cannot be accomplished anywhere else in the world.”

    The test launch is a culmination of months of preparation that involve multiple government partners.

    Airmen from all three missile wings were selected for the task force to support the test launch, while maintainers from the 90th Missile Wing Missile Wing at F.E. Warren Force Base, Wyoming, supported maintenance requirements. The missile bases within Air Fore Global Strike Command have crew members standing alert 24 hours a day, year-round, overseeing the nation’s ICBM alert forces. 

    The ICBM community, including the Department of Defense, the Department of Energy, and U.S. Strategic Command, uses data collected from test launches for continuing force development evaluation. The ICBM test launch program demonstrates the operational capability of the Minuteman III and ensures the United States’ ability to maintain a strong, credible nuclear deterrent as a key element of U.S. national security and the security of U.S. allies and partners.

    The Air Force is committed to ensuring Minuteman III remains a viable deterrent.

    MIL Security OSI

  • MIL-OSI Africa: Eco Atlantic Chief Executive Officer (CEO) to Speak at Invest in African Energy (IAE) 2025 Amid Orange Basin Expansion

    Source: Africa Press Organisation – English (2) – Report:

    PARIS, France, February 25, 2025/APO Group/ —

    Gil Holzman, President & CEO, Eco Atlantic Oil & Gas, will speak at the Invest in African Energy (IAE) Forum 2025 in Paris this May as the company expands its presence in the Orange Basin, offshore South Africa.

    The Canada-headquartered Eco Atlantic has recently expanded its presence in Africa through strategic transactions and exploration initiatives. In June 2024, Eco Atlantic farmed into Block 1 in the Orange Basin, further strengthening its exploration portfolio in the region. The block has extensive 2D and 3D seismic data already completed, with no additional seismic acquisition or well drilling planned during the three-year carried period. During this time, Eco will focus on interpreting and analyzing the existing data to inform its planned Work Program, leveraging its in-house exploration team. The company also holds interests in Blocks 2B and 3B/4B in South Africa, along with four licenses in Namibia.

    IAE 2025 (http://apo-opa.co/3ETVwbj) is an exclusive forum designed to facilitate investment between African energy markets and global investors. Taking place May 13-14, 2025 in Paris, the event offers delegates two days of intensive engagement with industry experts, project developers, investors and policymakers. For more information, please visit www.Invest-Africa-Energy.com. To sponsor or participate as a delegate, please contact sales@energycapitalpower.com.

    Eco Atlantic’s approach centers on exploring low-carbon intensity oil and gas in stable emerging markets close to infrastructure, aiming to deliver material value for its stakeholders while contributing to the energy transition. The company prioritizes efficient exploration strategies that minimize environmental impact while maximizing resource potential.

    By focusing on proven basins with existing infrastructure, Eco Atlantic seeks to accelerate development timelines and enhance economic viability in its operating regions. The upcoming forum will highlight how oil and gas independents like Eco Atlantic are navigating Africa’s evolving energy landscape, driving investment and sustainable resource development.

    MIL OSI Africa

  • MIL-OSI: Ponemon Cybersecurity Report: Insider Risk Management Enabling Early Breach Detection and Mitigation

    Source: GlobeNewswire (MIL-OSI)

    SAN JOSE, Calif., Feb. 25, 2025 (GLOBE NEWSWIRE) — DTEX Systems, the trusted leader of insider risk management, today announced the findings of the 2025 Cost of Insider Risks Global Report, independently conducted by the Ponemon Institute. For the first time since the inception of the report, the average time to contain an insider incident has declined (81 days, down from 86 in 2023).

    The decrease comes amid growing adoption of insider risk management solutions. The findings show that organizations are spending 16.5% of their annual IT security budget on insider risk management – up from 8.2% in 2023. Eighty-one percent of organizations now have or are planning to have an insider risk management program. Notably, of those with an insider risk management program, 65% say their program was the only security strategy that enabled them to pre-empt a data breach by detecting insider risk early. Meanwhile, 63% of respondents cited faster breach response as a top outcome of early insider risk detection.

    “With escalating foreign interference, global remote workforces, and a rapidly shifting political landscape, the need for proactive insider risk management has never been greater. Insider-driven security incidents result in significant financial and reputational costs. However, organizations investing in dedicated insider risk management programs are achieving faster containment or preventing incidents entirely—a decisive win in the fight against data loss,” DTEX Systems CEO Marshall Heilman said.

    “The findings underscore the importance of insider risk management as an essential component of security and highlight key opportunities for governments, critical infrastructure, and commercial organizations to protect sensitive data and maintain operational integrity in an increasingly volatile threat landscape.”

    Now in its sixth edition, the 2025 Cost of Insider Risks Global Report is a comprehensive study designed to understand the financial consequences of insider risks caused by negligent or mistaken employees, outsmarted employees (including insider incidents related to credential theft), or malicious insiders. This year’s report examines how organizations are funding their insider risk management programs and introduces new data evaluating the effectiveness.

    “Our research findings highlight the growing need to drive awareness of the increasing costs of insider risks, often occurring due to employee negligence while handling sensitive data,” Ponemon Institute Chairman and Founder Larry Ponemon said.

    “This study helps materialize risk by shining light on the increasing cost behind an incident to help organizations reduce containment time and ultimately, reduce cost.”

    Key findings of the 2025 Cost of Insider Risks Global Report include:

    • Post-incident activity costs have climbed significantly, contributing to a higher average annualized cost of insider risk: $17.4M — up from $16.2M in 2023. The average costs of containment ($211,021) and incident response ($154,819) are the most expensive activity cost centers (up from $179,209 and $113,635 in 2023 respectively). Escalation is the least costly activity center at $32,242.
    • For the first time since the inception of the report, the time to contain an insider incident has declined. The average time to contain an insider incident has reduced to 81 days, down from 86 days in 2023.
    • Insider risk management is affording companies a proactive approach to security through early insider risk detection. 65% said their insider risk management program was the only security strategy that effectively enabled them to pre-empt a data breach by detecting insider risk early.
    • Companies with an insider risk management program are saving time, money, and reputational damage associated with a breach. When asked the top three outcomes of having an insider risk management program, 63% said saved time in responding to a breach, 61% said protected brand reputation, and 59% said saved money lost in a breach.
    • Organizations are increasingly adopting insider risk management. The amount of IT security budget allocated to insider risk management has more than doubled, rising from 8.2% in 2023 to 16.5%. Additionally, 81% of companies now have or plan to have an insider risk management program, up from 77% in 2023.
    • Companies expect insider risk management budgets to increase. 45% say the current level of funding is inadequate. 46% expect a mild to significant increase in funding in 2025.
    • About half of organizations (49%) agree that technology consolidation is essential or very important. The top three driving factors, ranked by importance, are cost savings (85%), reduced complexity (64%), and faster detection times (61%), followed by scalability (48%), and actionable data (42%).
    • More than half (51%) of organizations say AI and machine learning are essential or very important in the detection and prevention of insider risks. The top three driving factors, ranked by importance, are reduced investigation times (70%), improved behavioral insights (59%), and lowered skillset for insider risk analysts (58%).
    • Health and pharma have the highest average activity costs. The average activity cost for health and pharma is $29.2M, followed by technology and software ($23M).
    • The most prevalent insider security incident continues to be caused by negligent or careless employees. 55% of incidents are due to employee negligence or mistakes, while 25% of incidents are caused by malicious insiders, and 20% by outsmarted insiders.

    Sponsored by DTEX Systems, the 2025 Cost of Insider Risks Global Report is based on responses from 8,306 IT and IT security practitioners in 349 organizations across North America, Europe, Middle East, Africa, and Asia-Pacific region.

    Read the complete 2025 Cost of Insider Risks Global Report here.

    Join Dr. Larry Ponemon, DTEX CTO Rajan Koo and national security veteran Christopher Burgess on March 12 for a webcast on the key findings and turning insights into action.

    About DTEX Systems
    As the trusted leader of insider risk management, DTEX transforms enterprise security by displacing reactive tools with a proactive solution that stops insider risks from becoming data breaches. DTEX InTERCEPT™ consolidates data loss prevention, user activity monitoring, and user behavior analytics in one lightweight platform to enable organizations to achieve a trusted and protected workforce. Backed by behavioral science, powered by AI, and used by governments and organizations around the world, DTEX is the trusted authority for protecting data and people at scale with privacy by design.

    To learn more about DTEX, visit dtexsystems.com
    Connect with DTEX: LinkedIn | Twitter | YouTube

    Media Contact
    Mariah Gauthier
    dtex@highwirepr.com

    The MIL Network

  • MIL-OSI: Cardinal Energy Ltd. Announces $40 Million Bought Deal Offering of Senior Subordinated Unsecured Debentures

    Source: GlobeNewswire (MIL-OSI)

    THE BASE SHELF PROSPECTUS IS ACCESSIBLE, AND THE PROSPECTUS SUPPLEMENT AND ANY AMENDMENT TO THE FOREGOING DOCUMENTS WILL BE ACCESSIBLE WITHIN TWO BUSINESS DAYS, ON SEDAR+

    NOT FOR DISTRIBUTION IN THE UNITED STATES.
    FAILURE TO COMPLY WITH THIS RESTRICTION MAY CONSTITUTE A VIOLATION OF UNITED STATES SECURITIES LAW

    CALGARY, Alberta, Feb. 25, 2025 (GLOBE NEWSWIRE) — Cardinal Energy Ltd. (“Cardinal” or the “Company”) (TSX: CJ) is pleased to announce that it has entered into an agreement with a syndicate of underwriters (the “Underwriters”) co-led by CIBC Capital Markets, RBC Capital Markets and ATB Capital Markets, with CIBC Capital Markets and RBC Capital Markets acting as joint-bookrunners, pursuant to which the Underwriters have agreed to purchase for resale to the public, on a bought deal basis, $40 million aggregate principal amount of senior subordinated unsecured debentures due September 30, 2030 (the “Debentures”) at a price of $1,000 per Debenture (the “Offering”). The Company has also granted the Underwriters an option to purchase up to an additional $5 million aggregate principal amount of Debentures, such option to be exercised in whole or in part at the sole discretion of the Underwriters, at any time until two business days prior to the Closing Date (as defined below). The Offering is expected to close on or about March 4, 2025 (the “Closing Date”).

    The Company intends to use the net proceeds of the Offering to first repay and reduce the indebtedness of its outstanding senior credit facility, then to de-risk the completion of the Company’s Reford thermal facility and accelerate the de-risking of the Company’s Kelfield thermal oil opportunity. As well the Company may use some of the proceeds for land and seismic acquisitions to delineate other thermal oil opportunities available to the Company.

    The Debentures will bear interest at a rate of 8.25% per annum, payable semi-annually in arrears on the last business day of March and September of each year commencing on September 30, 2025. The first payment will include accrued and unpaid interest for the period from the Closing Date to, but excluding, September 30, 2025. The Debentures will mature on September 30, 2030 (the “Maturity Date”).

    The Debentures will not be redeemable by the Company before September 30, 2028 (the “First Call Date”). On and after the First Call Date and prior to September 30, 2029, the Debentures will be redeemable, in whole or in part, from time to time at the Company’s option at a redemption price equal to 104.125% of the principal amount of the Debentures redeemed plus accrued and unpaid interest, if any, up to but excluding the date set for redemption. On and after September 30, 2029 and prior to the Maturity Date, the Debentures will be redeemable, in whole or in part, from time to time at the Company’s option at par plus accrued and unpaid interest, if any, up to but excluding the date set for redemption. The Company shall provide not more than 60 nor less than 30 days’ prior notice of redemption of the Debentures. The Company has the option to satisfy its obligations to repay the principal amount of and premium (if any) on the Debentures due at redemption or on maturity of the Debentures by issuing and delivering that number of freely tradeable common shares of the Company to Debenture holders in accordance with the terms of the debenture indenture that will govern the terms of the Debentures.

    The Debentures will be distributed in all provinces of Canada (other than the province of Quebec) by way of a prospectus supplement to the Company’s base shelf prospectus dated March 28, 2024 and by private placement in the United States to “qualified institutional buyers” pursuant to Rule 144A of the U.S. Securities Act of 1933.

    Access to the Base Shelf Prospectus, the Prospectus Supplement, and any amendments to the documents are provided in accordance with securities legislation relating to procedures for providing access to a base shelf prospectus, a prospectus supplement and any amendment to the documents. The Base Shelf Prospectus, the Prospectus Supplement (when filed) and any amendments to these documents may be accessed for free on the System for Electronic Document Analysis and Retrieval (“SEDAR+”) at www.sedarplus.ca. Alternatively, electronic or paper copies of the foregoing documents may be obtained, without charge, from: CIBC Capital Markets, 161 Bay Street, 5th Floor, Toronto, ON M5J 2S8 or by telephone at 1-416-956-6378 or by email at mailbox.canadianprospectus@cibc.com or from RBC Dominion Securities Inc., Attention: Distribution Centre, 180 Wellington Street West, 8th Floor, Toronto, ON M5J 0C2 or by email at Distribution.RBCDS@rbccm.com, by providing the contact with an email address or address, as applicable. The Offering is subject to customary regulatory approvals, including the approval of the TSX.

    This new release is not an offer of securities of Cardinal for sale in the United States. The securities have not been and will not be registered under the U.S. Securities Act of 1933, as amended, and the securities may not be offered or sold in the United States except pursuant to an applicable exemption from such registration. No public offering of securities is being made in the United States. This news release shall not constitute an offer to sell or the solicitation of an offer to buy nor shall there be any sale of the securities in any jurisdiction in which such offer, solicitation or sale would be unlawful.

    Note Regarding Forward-Looking Statements

    This press release contains forward-looking statements and forward-looking information (collectively “forward-looking information”) within the meaning of applicable securities laws relating to Cardinal’s plans and other aspects of Cardinal’s anticipated future operations, management focus, objectives, strategies, financial, operating and production results. Forward-looking information typically uses words such as “anticipate”, “believe”, “project”, “expect”, “goal”, “plan”, “intend”, “may”, “would”, “could” or “will” or similar words suggesting future outcomes, events or performance. The forward-looking statements contained in this press release speak only as of the date thereof and are expressly qualified by this cautionary statement. Specifically, this press release contains forward-looking statements relating to the anticipated closing date of the Offering and the use of proceeds of the Offering.

    Although Cardinal believes that the expectations reflected in these forward-looking statements are reasonable, undue reliance should not be placed on them because Cardinal 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. The intended use of the net proceeds of the Offering may change if the board of directors of Cardinal determines that it would be in the best interests of Cardinal to deploy the proceeds for some other purpose and the closing date for the Offering may be changed. The forward looking statements contained in this press release are made as of the date hereof and Cardinal undertakes no obligations to update publicly or revise any forward looking statements or information, whether as a result of new information, future events or otherwise, unless so required by applicable securities laws

    About Cardinal Energy Ltd.

    Cardinal is a Canadian oil and natural gas company with operations focused on low decline oil in Western Canada. Cardinal differentiates itself from its peers by having the lowest decline conventional asset base in Western Canada. Cardinal has recently announced the commencement of its first thermal SAGD oil development project which will further increase the long-term sustainability of the Company.

    For further information:

    M. Scott Ratushny, CEO or Shawn Van Spankeren, CFO, Laurence Broos, VP Finance or Cody Kwong, Manager Business Development Email: info@cardinalenergy.ca Phone: (403) 234-8681

    The MIL Network