Category: Energy

  • MIL-OSI Russia: Rosneft enterprises released more than 4.7 million valuable fish fry into Russian waters in July

    Translation. Region: Russian Federal

    Source: Rosneft – An important disclaimer is at the bottom of this article.

    Rosneft has been systematically working to preserve biological diversity and replenish the country’s aquatic bioresources for over 11 years. In July, the Company’s subsidiaries released more than 4.7 million young fish into Russian waters, including species listed in the Red Book.

    Together with employees of Rosneft subsidiaries, volunteers from the Movement of the First, students from partner universities and children of employees took part in environmental campaigns to stock water bodies with fish.

    Oil workers of Tyumenneftegaz sent 2.12 million muksun fry to the rivers and reservoirs of Siberia, Taas-Yuryakh Neftegazodobycha – 1.23 million peled, Kharampurneftegaz – 50 thousand nelma, RN-Purneftegaz – 457 thousand peled, 43 thousand muksun and 2 thousand nelma, SevKomNeftegaz – 357.7 thousand nelma, Angarsk Petrochemical Company – 10 thousand peled, RN-Uvatneftegaz – 2.9 thousand nelma.

    Employees of the Novokuibyshevsk Oil Refinery replenished the Volga bioresources with 11 thousand sterlet fry. Almost 9.5 thousand fry of this valuable fish species were released by Samaraneftegaz and 3.3 thousand by the Saratov Oil Refinery.

    The rearing and subsequent release of fry were carried out taking into account scientific data on the most favorable conditions for their adaptation in the natural environment and further reproduction.

    Preserving the environment for future generations is an integral part of the Rosneft-2030 strategy. The company and its subsidiaries aim to achieve leadership positions in minimizing environmental impact and environmentally friendly production, and are also implementing a number of comprehensive programs to preserve and restore natural resources.

    Rosneft employees actively participate in environmental campaigns and promote the development of a culture of rational and responsible consumption of natural resources. Volunteers from the Company’s enterprises regularly clean and improve the coastal areas of rivers, lakes and springs, and conduct environmental education classes in educational and preschool institutions.

    Department of Information and AdvertisingPJSC NK RosneftJuly 25, 2025

    Please note: This information is raw content obtained directly from the source of the information. It is an accurate report of what the source claims and does not necessarily reflect the position of MIL-OSI or its clients.

    .

    MIL OSI Russia News

  • MIL-OSI Asia-Pac: InvestHK visits UK to forge stronger Hong Kong-UK partnerships on sustainability and green tech innovation (with photos)

    Source: Hong Kong Government special administrative region

         ​Invest Hong Kong (InvestHK) completed a fruitful visit to the United Kingdom (UK) from July 13 to 20, championing Hong Kong as a premier international green technology hub for UK companies seeking growth and collaboration opportunities in Asia and beyond.

         During the visit, the Senior Vice President (Sustainability) for Technology, Innovation and Entrepreneurship at InvestHK, Ms Olivia To, engaged with key stakeholders in London and Cambridge to foster two-way business opportunities and deepen co-operation in sustainability and green tech innovation.

         In London, Ms To held extensive discussions with leading UK’s new energy, new materials and digital companies, as well as UK Research and Innovation, the national funding agency investing in science and research, Sustainable Ventures, a leading green tech hub and ecosystem provider, Generation Investment Management, a sustainable investment management firm, London & Partners, London’s business growth and destination agency, and London GreenCity, a clean technology entrepreneurs accelerator providing prototyping lab and collaborative community.

         In Cambridge, Ms To spoke at the event titled “Powering Tomorrow: Deep Tech Innovations for a Sustainable Energy Future”, co-organised by the University of Cambridge Institute for Sustainability Leadership and Full Vision Capital, highlighting the competitive advantages Hong Kong offers energy and technology companies to grow and thrive across the region. The conference featured dynamic keynotes on growth strategies for clean energy start-ups, panel discussions on disruptive energy innovations, and a start-up demo where over 30 start-ups showcased their cutting-edge solutions. The event culminated in the announcement of the 4th TERA-Award Winner receiving a prize of US$1 million and a celebratory Gala Dinner, fostering further global networking and collaboration opportunities.

         Ms To said, “Hong Kong’s unparalleled status as a global financial powerhouse connects the East and West markets, bolstered by its dynamic green tech ecosystem and visionary government initiatives like the Green Tech Fund, the Innovation and Technology Fund and the Hong Kong Science and Technology Parks Corporation’s GreenTech Hub, and positions it as the premier gateway for UK companies to amplify green innovations across Asia. This visit underscores our dedication to fostering collaboration in sustainability and green technology between Hong Kong and the UK. We look forward to supporting more UK companies in establishing and expanding their presence in Hong Kong, utilising our robust financial infrastructure to facilitate financing and IPO listings that attract international capital.”

         The Executive Chairman of the TERA-Award, Mr Alan Chan, stated, “It was our pleasure to have InvestHK’s participation in our TERA-Award event. Together, we are building a stronger global innovation ecosystem that connects investors, start-ups, and green organisations, fostering groundbreaking solutions in smart energy. We look forward to working closely with InvestHK to further expand our promotion of the TERA-Award to the global market and establish a bridge between the international energy contexts.”

         The Chief Innovation Officer from the Cambridge Institute for Sustainability Leadership, Mr James Cole, said, “We are delighted to welcome InvestHK’s participation in our event, enhancing the collaboration between the UK and Hong Kong economies, supporting sustainability start-ups and strengthening the ecosystem. This collaboration ignites our commitment to forge global partnerships that will propel deep tech innovations, fostering a greener and more resilient future. Together, we anticipate to deepen our collaboration to accelerate the transition to a sustainable future and empower the next generation of innovators.”

         Co-Founder of London GreenCity Mr Laith Anezi said, “Both Hong Kong and the UK share a strong commitment to driving innovation in green technology. InvestHK’s visit has forged a robust foundation for strengthening ties between Hong Kong and British sustainability and green tech companies. We are excited to deepen our partnership with InvestHK, driving innovation to shape a sustainable world together.”

         Hong Kong, as the world’s third-largest financial hub, is well positioned to be the global leader in green tech and finance. The city is transitioning to cleaner energy sources, targeting carbon neutrality by 2050, supported by the Strategy of Hydrogen Development in Hong Kong and significant investments in the Hetao Shenzhen-Hong Kong Science and Technology Innovation Co-operation Zone.

         In green mobility, Hong Kong’s roadmap for electric vehicles has seen 70 per cent of newly registered private cars in 2024 be electric, with plans to establish the city as a green maritime fuel bunkering centre.

         This visit to the UK is a testament to Hong Kong’s dedication to fostering international collaboration and driving the global transition to a sustainable future. By attracting more UK companies in sustainable technology and innovation, Hong Kong aims to accelerate the adoption of innovative solutions that address the world’s most pressing environmental challenges.

    MIL OSI Asia Pacific News

  • MIL-OSI: Webcast details for Orrön Energy’s Q2 presentation

    Source: GlobeNewswire (MIL-OSI)

    Orrön Energy AB (“Orrön Energy”) will publish its financial report for the second quarter 2025 on Wednesday, 6 August 2025 at 07:30 CEST, followed by a webcast at 14:00 CEST.

    Listen to Daniel Fitzgerald, CEO and Espen Hennie, CFO commenting on the report and describing the latest developments in Orrön Energy at a webcast on 6 August 2025 at 14:00 CEST, followed by a question-and-answer session.

    Registration for the webcast presentation is available on the website and the below link:
    https://orron-energy.events.inderes.com/q2-report-2025

    For further information, please contact:

    Robert Eriksson
    Corporate Affairs and Investor Relations
    Tel: +46 701 11 26 15
    robert.eriksson@orron.com

    Jenny Sandström
    Communications Lead
    Tel: +41 79 431 63 68
    jenny.sandstrom@orron.com

    Orrön Energy is an independent, publicly listed (Nasdaq Stockholm: “ORRON”) renewable energy company within the Lundin Group of Companies. Orrön Energy’s core portfolio consists of high quality, cash flow generating assets in the Nordics, coupled with greenfield growth opportunities in the Nordics, the UK, Germany and France. With significant financial capacity to fund further growth and acquisitions, and backed by a major shareholder, management and Board with a proven track record of investing into, leading and growing highly successful businesses, Orrön Energy is in a unique position to create shareholder value through the energy transition.

    Forward-looking statements
    Statements in this press release relating to any future status or circumstances, including statements regarding future performance, growth and other trend projections, are forward-looking statements. These statements may generally, but not always, be identified by the use of words such as “anticipate”, “believe”, “expect”, “intend”, “plan”, “seek”, “will”, “would” or similar expressions. By their nature, forward-looking statements involve risk and uncertainty because they relate to events and depend on circumstances that could occur in the future. There can be no assurance that actual results will not differ materially from those expressed or implied by these forward-looking statements due to several factors, many of which are outside the company’s control. Any forward-looking statements in this press release speak only as of the date on which the statements are made and the company has no obligation (and undertakes no obligation) to update or revise any of them, whether as a result of new information, future events or otherwise.

    Attachment

    The MIL Network

  • Iran and Europeans begin nuclear talks with questions over future UN sanctions

    Source: Government of India

    Source: Government of India (4)

    Iran pushed back on Friday on suggestions of extending a U.N. resolution that ratifies a 2015 nuclear deal as it began the first face-to-face talks with Western powers since Israel and the U.S. bombed it last month.

    Delegations from Iran, the European Union and the E3 group of France, Britain and Germany, arrived for talks at the Iranian consulate in Istanbul.

    The European countries, along with China and Russia, are the remaining parties to a 2015 deal – from which the U.S. withdrew in 2018 – that lifted sanctions on Iran in return for restrictions on its nuclear programme.

    A deadline of Oct. 18 is fast approaching when the resolution governing that deal expires.

    At that point, all U.N. sanctions on Iran will be lifted unless a “snapback” mechanism is triggered at least 30 days before. This would automatically reimpose those sanctions, which target sectors from hydrocarbons to banking and defence.

    To give time for this to happen, the E3 have set a deadline of the end of August to revive diplomacy. Diplomats say they want Iran to take concrete steps to convince them to extend the deadline by up to six months.

    Iran would need to make commitments on key issues including eventual talks with Washington, full cooperation with the International Atomic Energy Agency, and accounting for 400 kg (880 pounds) of near-weapons grade highly enriched uranium, whose whereabouts are unknown since last month’s strikes.

    Minutes before the talks began, Iranian Foreign Ministry spokesperson Esmaeil Baghaei told the state news agency IRNA that Iran considered talk of extending U.N. Security Council Resolution 2231 to be “meaningless and baseless”.

    The United States held five rounds of talks with Iran prior to its airstrikes in June, which U.S. President Donald Trump, said had “obliterated” a programme that Washington and its ally Israel say is aimed at acquiring a nuclear bomb.

    However, NBC News has cited current and former U.S. officials as saying a subsequent U.S. assessment found the strikes destroyed most of one of three targeted Iranian nuclear sites, but that the other two were not as badly damaged.

    Iran denies seeking a nuclear weapon.

    European and Iranian diplomats say there is no prospect of Iran re-engaging with the U.S. at the negotiating table for now.

    (Reuters)

  • MIL-OSI United Kingdom: Statement on Australia-UK Ministerial Consultations (AUKMIN) July 2025

    Source: United Kingdom – Executive Government & Departments

    Press release

    Statement on Australia-UK Ministerial Consultations (AUKMIN) July 2025

    Joint statement from UK and Australia on the Australia-UK Ministerial Consultations (AUKMIN) July 2025

    1 . On 25 July 2025, the Minister for Foreign Affairs Senator the Hon Penny Wong and the Deputy Prime Minister and Minister for Defence the Hon Richard Marles MP hosted the Secretary of State for Foreign, Commonwealth and Development Affairs the Rt Hon David Lammy MP and the Secretary of State for Defence the Rt Hon John Healey MP for the Australia-UK Ministerial Consultations (AUKMIN) in Sydney.

    2 . Ministers noted the global security environment had become more dangerous and unpredictable since they last met in December 2024. They recognised the elevated importance of the enduring Australia-UK relationship in responding together to address these challenges.

    3 . Ministers agreed to significantly increase their cooperation to bolster Australia and the UK’s defence and national security, enhance economic security and mitigate and address the impacts of climate change. Ministers agreed on the enduring importance of the UK-Australia relationship in delivering economic growth to our peoples and globally.

    4 . Ministers underscored the role Australia and the UK play in upholding the rules, norms and institutions, including respect for universal human rights, that underpin global prosperity and security, and noted their deep, clear and longstanding commitment to the multilateral system. They committed to consider joint initiatives and advocacy on multilateral reform, including on the UN Secretary-General’s UN80 Initiative, to ensure the multilateral system is able to continue to deliver on critical core functions and mandates.

    Closer cooperation in the Indo-Pacific

    5 . Ministers reaffirmed that the security, resilience and prosperity of the Indo-Pacific and Euro-Atlantic regions are interconnected. They committed to continue to expand efforts to safeguard internationally agreed rules and norms and respect for sovereignty. Ministers agreed on the need to shape a world characterised by adherence to rules and norms, rather than power or coercion.

    6 . Ministers committed to further strengthen cooperation, bilaterally and with regional partners, to ensure a peaceful, stable and prosperous Indo-Pacific. Ministers agreed the UK and Australia’s enduring engagement in the Indo-Pacific was important to shaping a favourable strategic balance in the region.

    7 . Recognising the deteriorating geostrategic environment, Ministers emphasised the need for all countries to manage strategic competition responsibly, and the importance of dialogue and practical measures to reduce the risks of miscalculation, escalation and conflict.

    8 . Ministers reiterated their strong opposition to coercive or destabilising activities by China’s Coast Guard, naval vessels and maritime militia in the South China Sea, including sideswiping, water cannoning and close manoeuvres that have resulted in injuries, endangered lives and created risks of miscalculation and escalation. Ministers agreed to continue cooperating to support freedom of navigation and overflight in the region, including through participation in joint activities. They also reiterated their concern about the situation in the East China Sea.

    9 . Ministers emphasised the obligation of all states to adhere to international law, particularly the United Nations Convention on the Law of the Sea (UNCLOS), which provides the comprehensive legal framework for all activities in the ocean and seas. They agreed that maritime disputes must be resolved peacefully and in accordance with international law. Ministers reaffirmed that the 2016 South China Sea Arbitral Tribunal decision is final and binding on the parties. They emphasised any South China Sea Code of Conduct must be consistent with UNCLOS and not undermine the rights of States under international law.

    10 . Ministers agreed on the critical importance of peace and stability across the Taiwan Strait. They called for the peaceful resolution of cross-Strait issues through dialogue and not through the threat or use of force or coercion, and reaffirmed their opposition to unilateral changes to the status quo. They expressed concern at China’s destabilising military exercises around Taiwan. Ministers recognised that the international community benefits from the expertise of the people of Taiwan and committed to support Taiwan’s meaningful participation in international organisations where statehood is not a pre-requisite or as an observer or guest where it is. They reiterated their will to continue to deepen relations with Taiwan in the economic, trade, scientific, technological, and cultural fields.

    11 . Ministers strongly condemned the DPRK’s ongoing nuclear and ballistic missile programs and called for the complete, verifiable and irreversible denuclearisation of the DPRK. Ministers also expressed grave concern over the DPRK’s malicious cyber activity, including cryptocurrency theft and use of workers abroad to fund the DPRK’s unlawful weapons of mass destruction and ballistic missile programs.

    12 . Ministers emphasised their commitment to ASEAN centrality and recognised the critical role of ASEAN-led architecture in promoting peace, stability and prosperity in the region. They reaffirmed their ongoing commitment to support the practical implementation of the ASEAN Outlook on the Indo-Pacific.

    13 . Ministers underscored their commitment to deepen engagement on trade and investment diversification in Southeast Asia, including through Invested: Australia’s Southeast Asia Economic Strategy to 2040, Australia’s AUD 2 billion Southeast Asian Investment Financing Facility and dedicated Southeast Asia Investment Deal Teams, and the UK’s enhanced economic engagement. Ministers agreed to continue to strengthen coordination on clean energy transition in Southeast Asia and cooperation to bolster the region’s economic resilience through the mobilisation of private finance for climate objectives and green infrastructure, exploring collaboration on financing of low-carbon energy projects, and coordination of support to the ASEAN Power Grid.

    14 . Ministers reaffirmed their commitment to combat people smuggling, human trafficking and modern slavery in South and Southeast Asia, recognising that women and girls were most impacted, with a focus on trafficking into scam centres.

    15 . Ministers reiterated their commitment to the Indian Ocean Rim Association (IORA) as the premier ministerial-level forum in the Indian Ocean region. They agreed to continue collaboration on shared priorities in the Indian Ocean, including maritime security.

    16 . Ministers reiterated their serious concern at the deepening humanitarian crisis and escalating violence in Myanmar, compounded by the devastating earthquake in March. They strongly condemned the Myanmar regime’s violent oppression of its people, including the continued bombardment of civilian infrastructure. They called for all parties to prioritise the protection of civilians. They called on the regime to immediately cease violence, release those arbitrarily detained, allow safe and unimpeded humanitarian access, and return Myanmar to the path of inclusive democracy. Ministers reiterated their support for ASEAN’s efforts to resolve the crisis, including through the Five Point Consensus and the work of the ASEAN Special Envoy and UN Special Envoy. They welcomed ASEAN leaders’ recent call for an extended and expanded ceasefire, and inclusive national dialogue.

    17 . Ministers highlighted their commitment to continue to work with Pacific island countries through existing regional architecture, recognising the centrality of the Pacific Islands Forum. They agreed on the importance of pursuing Pacific priorities as set out in the 2050 Strategy for the Blue Pacific Continent. Ministers joined Pacific partner calls for increased access to climate finance, including further support to Pacific-owned and led mechanisms such as the Pacific Resilience Facility. Ministers welcomed ongoing reform of multilateral climate funds, including the Green Climate Fund (GCF), to provide better outcomes for Pacific island countries, noting encouraging progress made regarding the accreditation of Direct Access Entities and GCF regional presence. Ministers welcomed the UK’s continued contributions to Pacific security through their assistance in the removal of explosive remnants of war via their participation in the Australian-led Operation Render Safe. Ministers agreed to continue to work together to advance transparent and high-quality development in line with the Pacific Quality Infrastructure Principles (PQIPs), including through the Pacific Business Club. Ministers committed to work collaboratively on respective approaches to the Multilateral Development Banks (MDBs) to encourage reform consistent with the PQIPs. Ministers underscored our shared commitment to cyber coordination and capacity-building in the Pacific including through support to the inaugural Pacific Cyber Week in August 2025, a concept endorsed by the Pacific Islands Forum. Ministers emphasised the importance of sharing expertise and strengthening people-to-people links for a more cyber-resilient Pacific.

    Ambitious partners, facing global challenges together

    18 . Ministers unequivocally condemned Russia’s full-scale invasion of Ukraine and called on Russia to immediately withdraw its troops from Ukraine’s internationally recognised territory, and adhere fully to its obligations under international law, including in relation to the protection of civilians and treatment of prisoners of war. They reiterated their commitment to making sure that Ukraine gets the military and financial support it needs to defend itself in the fight now and agreed to step up action against Russia’s war machine. They emphasised the importance of taking further action against Russia’s shadow fleet, acknowledging the sanctions both countries had imposed in this regard. They also called on Russia to immediately cease their illegal deportation of Ukrainian children and reunify those already displaced with their families and guardians in Ukraine.

    19 . Ministers reiterated their deep concerns about the role of third countries in supporting Russia’s illegal war in Ukraine and the associated impact for the security of the Indo-Pacific. They called on China to prevent its companies from supplying dual-use components to Russia’s war effort, and exercise its influence with Russia to stop Moscow’s military aggression and enter negotiations to end the war in good faith. Ministers strongly condemned the DPRK’s support for Russia through the supply of munitions and deployment of DPRK personnel to enable Russia’s war efforts. Ministers called on Iran to cease all support for Russia’s illegal war against Ukraine and halt the transfer of ballistic missiles, UAVs and related technology.

    20 . Ministers agreed deepening military cooperation between Russia and the DPRK was a dangerous expansion of Russia’s war that has significant implications for security in the Indo-Pacific region. They expressed deep concerns about any political, military or economic support Russia may be providing to the DPRK’s nuclear and ballistic missile programs. Ministers affirmed their commitment to cooperating with international partners to strengthen efforts to hold the DPRK to account for violations and evasions of UN Council Resolutions (UNSCRs) including as founding members of the Multilateral Sanctions Monitoring Team (MSMT). Ministers acknowledged the release of the MSMT’s first report, which shines a light on unlawful DPRK-Russia military cooperation including arms transfers and Russia’s training of DPRK troops. Ministers urged all UN Member States to abide by their international obligations under the UNSCRs to implement sanctions, including the prohibition on the transfer or procurement of arms and related material to or from the DPRK.

    21 . Ministers called on Iran and Israel to adhere to the ceasefire and urged Iran to resume negotiations with the US. Ministers stated their determination that Iran must never develop a nuclear weapon. It is essential that Iran act promptly to return to full compliance with its safeguards obligations, cooperate fully with the International Atomic Energy Agency, and refrain from actions that would compromise efforts to address the security situation in the Middle East. Ministers condemned Iran’s unjust detention of foreign nationals and raised ongoing concerns over the human rights situation in Iran, particularly the escalation of the use of the death penalty as a political tool during the 12-day conflict, and the ongoing repression of women, girls and human rights defenders.

    22 . Ministers reiterated their support for Israel’s security and condemnation of Hamas’ horrific attacks on 7 October 2023, and underlined that Israeli actions must abide by international law. They called for an immediate ceasefire in Gaza, an end to Israeli blocks on aid, and the urgent and unconditional release of all hostages.

    23 . Ministers reaffirmed their conviction that an immediate and sustained ceasefire, alongside urgent steps towards a credible and irreversible pathway to a two-state solution are the only ways to deliver lasting peace, security and stability for Israelis, Palestinians and the wider region.

    24 . Ministers expressed grave concerns at the horrific and intolerable situation in Gaza. They continue to be appalled by the immense suffering of civilians, including Israel’s blocking of essential aid. They reiterated their call for Israel to immediately enable full, safe and unhindered access for UN agencies and humanitarian organisations to work independently and impartially to save lives, end the suffering and deliver dignity. Ministers also condemned settler violence in the West Bank, which has led to deaths of Palestinian civilians and the displacement of whole communities, and expressed opposition to any attempt to expand Israel’s illegal settlements.

    25 . Ministers expressed their deep concern for the safety and security of humanitarian personnel working in conflict settings around the world. They reaffirmed their commitment to finalise a Declaration for the Protection of Humanitarian Personnel and implement practical actions to ensure greater respect for and protection of humanitarian personnel. Ministers also called on all countries to endorse the Declaration once launched and to reaffirm their responsibility to uphold humanitarian principles and ensure respect for international humanitarian law. Ministers discussed the essential role of the humanitarian system which is critical to saving lives and livelihoods and avoiding mass displacement. Ministers noted that the core work of the UN, the Red Cross and Red Crescent Movement, and international, national and local humanitarian organisations, must be preserved. Ministers also reiterated support for the Emergency Relief Coordinator’s humanitarian reset.

    26 . Ministers committed to continue close collaboration on protecting and promoting gender equality internationally and countering rollback of rights, including through Australia-UK Strategic Dialogues on Gender Equality and progressing subsequent agreed commitments, such as the UK-Australia Gender Based Violence MoU.

    27 . Ministers reaffirmed their commitment to the full implementation of the Women Peace and Security (WPS) agenda. They acknowledged the 25th anniversary of UN Security Council Resolution 1325 and agreed to continue working together on implementing the WPS agenda, promoting the full, equal, meaningful and safe participation and leadership of women in conflict prevention, mediation and resolution, and working together on preventing conflict-related sexual violence and ending impunity.

    28 . Ministers reiterated their serious shared concerns about human rights violations in China, including the persecution and arbitrary detention of Uyghurs and Tibetans and the erosion of their religious, cultural, education and linguistic rights and freedoms. They expressed their deep concern with the transfer of a cohort of 40 Uyghurs to China against their will in February this year. Ministers shared grave concerns about the ongoing systemic erosion of Hong Kong’s autonomy, freedom, rights and democratic processes, including through the imposition of national security legislation and the prosecution of individuals such as British national Jimmy Lai and Australian citizen Gordon Ng. They shared their deep concern over the actions of Hong Kong authorities in targeting pro-democracy activists both within Hong Kong and overseas, including in Australia and the UK.

    29 . Ministers expressed growing concern over foreign information manipulation and interference (FIMI) and attempts to undermine security and democratic institutions and processes. They committed to working closely to analyse and respond to FIMI in order to raise the costs for malign actors, and build collective responses to FIMI, including in multilateral fora, and to promote resilient, healthy, open and fact-based environments.

    30 . Ministers acknowledged the unprecedented opportunities presented by critical and emerging technologies, including artificial intelligence, and the need to mitigate harms to build trust and confidence. They committed to collaborate on reciprocal information sharing on advanced AI capabilities and research, including between Australian agencies and the UK AI Security Institute, and working together to capture the opportunities of AI through the bilateral Cyber and Critical Technology Partnership.

    31 . Australia welcomed the UK’s new Laboratory for AI Security Research (LASR) and looked forward to exploring the opportunities for cooperation between our nations. The lab will pull together our world-class industry, academia and government agencies to ensure we reap the benefits of AI, while detecting, disrupting and deterring adversaries who would use it to undermine our national security and economic prosperity.

    32 . Ministers expressed shared concern over the persistent threat of malicious cyber activities impacting our societies and economies and agreed to continue to work closely on leveraging all tools of deterrence, including the use of attributions and sanctions to impose reputational, financial costs and travel bans on these actors. Our respective statements calling out the egregious activity of Russia’s GRU on Friday 18 July is a good example of such cooperation.

    33 . The UK is pleased to welcome Australia as a partner to the Common Good Cyber Fund, designed to strengthen cybersecurity for individuals most at risk from digital transnational repression. The Fund was first launched by the Prime Ministers of the UK and Canada under the G7 Rapid Response Mechanism. This participation underscores the growing commitment among G7 partners and like-minded nations to counter this threat and to deliver support to those who may be targeted.

    34 . Ministers reiterated their commitment to the Commonwealth as a unique platform for cross-regional dialogue and cooperation. They noted the importance of the Commonwealth in elevating the voices of small developing states on issues of global importance. Ministers took note of the important role of the Commonwealth Small States Offices in New York and Geneva, and committed to looking into options for expansion of this offer.

    Building shared defence capability

    35 . Ministers welcomed the continued growth in the bilateral defence relationship including the deployment of a British Carrier Strike Group to Australia for Exercise Talisman Sabre 2025 as part of an Indo-Pacific deployment. HMS Prince of Wales is the first UK aircraft carrier to visit Australia since 1997 and the deployment demonstrates the UK’s ongoing commitment to increase interoperability with Australia in the Indo-Pacific following significant contributions to Exercises Pitch Black and Predator’s Run in 2024. Ministers look forward to future opportunities in Australia and the wider region, including leveraging the Royal Navy’s (RN) offshore patrol vessels persistently deployed in the Indo-Pacific.

    36 . Ministers also welcomed the success of the inaugural Australia-UK Staff Level Meeting, with the second meeting set to take place in Australia later this year. This forum will continue to progress joint strategic and operational objectives, supporting the evolution of the bilateral relationship.

    37 . Ministers reaffirmed their enduring commitment to the generational AUKUS partnership, which is supporting security and stability in the Indo-Pacific and beyond, enhancing our collective deterrence against shared threats. This capability and technology sharing partnership will deliver military advantage to deter adversaries and promote regional security. The partnership also provides new pathways for innovation, boosting interoperability between partners and strengthening our combined defence industrial base.

    38 . Ministers announced their intent to sign a bilateral AUKUS treaty between the UK and Australia on Saturday, 26 July. The Treaty is a landmark agreement, which will underpin the next 50 years of UK-Australian bilateral cooperation under AUKUS Pillar I.

    39 . The Treaty will enable comprehensive cooperation on the design, build, operation, sustainment, and disposal of our SSN-AUKUS submarines; support the development of the personnel, workforce, infrastructure and regulatory systems required for Australia’s nuclear-powered submarine program; and realise increased port visits and the rotational presence of a UK Astute Class submarine at HMAS Stirling under Submarine Rotational Force – West.

    40 . The Treaty will enable our two countries to deliver a cutting-edge undersea capability through the SSN-AUKUS, in conjunction with our partner the US. Through working together we are supporting stability and security in the Indo-Pacific and beyond for decades to come, creating thousands of jobs, strengthening our economies and supply chains, building our respective submarine industrial bases and providing new opportunities for industry partners.

    41 . Ministers welcomed the significant progress made towards delivering Pillar I, including the entry into force of the AUKUS Naval Nuclear Propulsion Agreement between Australia, the UK and US on 17 January 2025 and the progress in design of the SSN-AUKUS submarines that will be operated by the RN and the Royal Australian Navy (RAN).

    42 . Ministers welcomed the UK’s June commitment, in its Strategic Defence Review, to build up to 12 SSN-A submarines, and continuous submarine production through investments in Barrow and Raynesway that will allow the UK to produce a submarine every 18 months, and recognised the UK’s additional investment to transform the UK’s submarine industrial base.

    43 . Ministers reaffirmed Australia and the UK’s strong and ongoing commitment to the delivery of the AUKUS Optimal Pathway. Reflecting the UK’s enduring dedication to this partnership, and long-standing engagement in the Indo-Pacific, Ministers welcomed the planned deployment of a RN submarine to undertake a port visit to Australia in 2026, delivering a varied programme of operational and engagement activities. The visit will support preparations for the establishment of the Submarine Rotational Force – West from as early as 2027, and represents another step forward on the shared path towards the delivery of SSN-AUKUS – ensuring our navies are ready, integrated, and capable of operating together to promote security and stability in the region.

    44 . Ministers underscored the importance of ensuring Australia’s acquisition of a conventionally-armed, nuclear-powered submarine capability sets the highest non-proliferation standard, and endorsed continued close engagement with the International Atomic Energy Agency.

    45 . Ministers affirmed their commitment under AUKUS Pillar II to continue to deliver tangible advanced capabilities to our defence forces and welcomed progress to date. By leveraging advanced technologies, our forces become more than the sum of their parts. They underlined the importance of Pillar II in streamlining capability acquisition and strengthening our defence innovation and industry sectors.

    46 . As part of Talisman Sabre 25, AUKUS partners participated in Maritime Big Play activities as well as groundbreaking AI and undersea warfare trials. The partners tested the remote operation of the UK’s Extra Large Unmanned Underwater Vehicle, Excalibur, controlled from Australia while operating in UK waters. The exercise once again accelerated interoperability between our forces and the accelerated integration of remote and autonomous systems.

    47 . Ministers noted the successful UK E-7A Seedcorn training program in Australia. The program, which is set to conclude in December 2025, was established to preserve a core of Airborne Early Warning and Control expertise within the Royal Air Force (RAF) and to lay a strong foundation for the introduction of the UK’s own Wedgetail aircraft. Thanks to the exceptional support of the Royal Australian Air Force (RAAF), since its inception in 2018, 30 RAF personnel – including pilots, mission crew, engineer officers, aircraft technicians, and operations specialists – have benefited from world-class training and exposure to the Wedgetail capability.

    48 . Ministers welcomed the upcoming deployment of a RAAF E-7A Wedgetail to Europe in August under Operation Kudu to help protect vital supply lines for humanitarian aid and military assistance into Ukraine. Delivering upon the vision for true interchangeability detailed in the Wedgetail Trilateral Joint Vision Statement in 2023, this deployment will see the Wedgetail jointly crewed by Australian and British service members in a live operational setting.  Ministers also welcomed Australia’s decision to extend support for training Ukrainian personnel under Operation Interflex, through Operation Kudu, to the end of 2026. Australia and the UK will also continue to work closely together to share insights and observations from the conflict.

    49 . Ministers reiterated their nations’ continued investment in the Five Power Defence Arrangements (FPDA) as a unique multilateral arrangement that plays a constructive role in building habits of cooperation and enhancing the warfighting capabilities of its members. They look forward to Exercise Bersama Lima 2025 which will feature high-end warfighting serials and next-generation assets such as Australia’s F-35s and the UK’s Carrier Strike Group.

    50 . Ministers affirmed their shared ambition to conduct a bilateral defence industry dialogue at both the Senior Official and Ministerial levels, providing a forum to deepen defence industry collaboration, enhance joint capability development, and cooperate on procurement reform to ensure improved efficiency in capability acquisition and sustainment.

    51 . Ministers agreed to deepen cooperation on using Active Electronically Scanned Array (AESA) radar technology in both nations. This includes exploring the potential of using Australian AESA radar technologies for UK integrated air and missile defence applications. They agreed to undertake a series of targeted risk reduction activities in the near future to inform future decisions.”

    52 . Ministers agreed to progress personnel exchanges that support the future combat effectiveness of the Australian Hunter Class and British Type 26 Frigates. To support the introduction of these platforms into service, the RAN and RN will undertake a series of maritime platform familiarisation activities that enable our people to gain experience in critical capabilities, including underwater and above water weapon systems, primary acoustical intelligence analysis, and overall signature management.

    53 . Ministers agreed to strengthen their sovereign defence industries through closer collaboration between the UK’s Complex Weapons Pipeline and Australia’s Guided Weapons and Explosive Ordnance Enterprise. As a first step the Ministers announced a collaborative effort to develop modular, low cost components for next-generation weapon systems.

    54 . Ministers acknowledged the shared legacy and the contribution of veterans to the bilateral relationship. They reaffirmed their commitment to identify avenues for closer collaboration on improving veterans’ health and transition services.

    Partnering on trade, climate and energy

    55 . Ministers agreed to work closely to safeguard and strengthen the role that free and fair trade and the rules-based multilateral trading system plays in economic prosperity and building resilience against economic shocks.

    56 . Ministers reaffirmed the importance of the rules-based multilateral trading system, with the World Trade Organization (WTO) at its core, to economic security and prosperity. Ministers agreed to deepen cooperation to reform and reposition the Organization, and the broader global trading system, to meet the trade challenges of the new economic and geopolitical environment. Ministers agreed to continue working together to overcome blockages in multilateral rulemaking, including by working in smaller and more agile plurilateral groupings to address contemporary challenges, such as non-market policies and practices, which could complement ongoing multilateral efforts. They welcomed cooperation on plurilateral rulemaking, including efforts to have the E-Commerce Agreement incorporated into WTO architecture and brought into force as soon as possible. They reaffirmed the importance of restoring a fully-functioning dispute settlement system as soon as possible, welcoming the UK’s decision to join the Multi-Party Interim Appeal Arbitration Arrangement (MPIA) while our countries work to fix the system.

    57 . Ministers welcomed the entry into force of the UK’s accession to the Comprehensive and Progressive Agreement for Trans-Pacific Partnership (CPTPP) in December 2024 and welcomed Australia as 2025 Chair. Ministers affirmed the need to work cooperatively together to ensure the CPTPP remains high standard and fit-for-purpose in addressing evolving challenges through continued progress on the CPTPP General Review and expansion of the membership. They looked forward to planned CPTPP trade and investment dialogues with the EU and with ASEAN.

    58 . Ministers welcomed the second meeting of the Australia-United Kingdom Free Trade Agreement (A-UKFTA) Joint Committee on 3 June which celebrated the strong and growing trade and investment relationship between the UK and Australia and the strong uptake of the agreement’s benefits.

    59 . Ministers welcomed close engagement on economic security under the annual United Kingdom-Australia Economic Security Dialogue, noting that its establishment by AUKMIN in 2023 was timely in preparing for future needs. They reflected on the closer integration of our analysis capabilities and committed to a joint-funded track 1.5 to generate practical insights and informal policy dialogue that will inform our joint economic security efforts.

    60 . As both countries continue to develop their bilateral partnership through the UK-Australia FTA, the Economic Security Dialogue, and other fora, Ministers committed to deepening cooperation in key sectors of mutual interest. Ministers view this as an opportunity to explore new areas of collaboration and share best practices in the interests of boosting bilateral trade and investment, facilitating innovation and research, and supporting our mutual economic security and resilience. This year, officials in relevant departments will compare approaches with the aim to identify areas of common interest or complementary strength and discuss further opportunities for related cooperation. This may include initiatives to advance supply chain resilience, frontier research, investment promotion, public finance cooperation, and effective regulation.

    61 . Ministers affirmed the calls in the Global Stocktake under the Paris Agreement for countries to come forward in their next NDCs with ambitious emissions reduction targets aligned with keeping 1.5 degrees within reach. In that context, Ministers recognised the immense economic opportunities in ambitious climate action and a rapid transition to renewable energy. Ministers welcomed the UK’s ambitious NDC and looked forward to Australia’s NDC and Net-Zero Plan. Ministers further welcomed the report released by the UN Secretary General titled ‘Seizing the Moment of Opportunity: Supercharging the new energy era of renewables, efficiency, and electrification’ that highlighted the compelling economic case for the rapidly declining cost of renewable energy, and the rapidly growing role of the clean energy economy in powering jobs and economic growth. Ministers affirmed their determination to fulfil multilateral climate commitments and reiterated the importance of reforming the finance system and improving access to climate finance for developing countries. Ministers recommitted to building nature-positive economies to support a central theme of Brazil’s COP Presidency. The UK reiterated its support for Australia’s bid to host COP31 in partnership with the Pacific and expressed the hope that a decision would soon be reached. Ministers welcomed UK sharing its hosting experience and agreed to explore secondments to support COP31 planning. The UK and Australia welcome the close collaboration between our countries in the Intergovernmental Negotiating Committee (INC) negotiations for an international legally binding instrument on plastic pollution, including through our shared membership of the High Ambition Coalition to End Plastic Pollution. At this critical juncture ahead of INC-5.2, the final opportunity to secure an agreement, we call upon all members of the INC to recommit to working constructively to achieve an effective comprehensive agreement that addresses the full lifecycle of plastic. We recognise that Commonwealth countries are particularly affected by plastic pollution and in that regard we renew our commitment to collaborating through the Commonwealth Clean Ocean Alliance, to tackle plastic pollution in the commonwealth. Ministers pledged to deepen collaboration through the UK-Australia Climate and Clean Energy Partnership.

    62 . Ministers welcomed close cooperation to support the development of resilient critical mineral supply chains governed by market principles. This includes developing a roadmap to promote a standards-based market to reflect the real costs of responsible production, processing and trade of critical minerals as agreed at the recent G7 meeting on 17 June. Ministers agreed upon the importance of the sustainable and responsible extraction and processing of critical minerals for the energy transition, and committed to working together on solutions. These include the new Critical Minerals Supply Finance developed by UK Export Finance (UKEF) which can provide finance support to overseas critical minerals projects that supply the UK’s high-growth sectors. UKEF has up to £5bn in finance support available for projects in Australia and will work closely with Export Finance Australia. Ministers also undertook to ensure the UK is consulted on the design and implementation of Australia’s Critical Minerals Strategic Reserve.

    63 . Ministers discussed the leading roles being played by Australia and the UK in the full and effective implementation of the Biodiversity Beyond National Jurisdiction (BBNJ) Agreement welcoming in particular Australia’s role as Co-Chair of the Preparatory Commission. Ministers were encouraged by each country’s progress towards ratification of the treaty, which is a landmark agreement for protection of the world’s ocean.

    64 . Ministers discussed the increasing geostrategic, climatic, and resource pressures on the Antarctic and Southern Ocean region and reaffirmed their shared and long-standing commitment to the Antarctic Treaty System (ATS). Ministers committed to upholding together the ATS rules and norms of peaceful use, scientific research, international cooperation and environmental protection, and to deepen understanding of the impact of climate change on the oceans and the world through Antarctic research including in the context of the International Polar Year of 2032/33. Ministers welcomed the United Kingdom’s chairing of CCAMLR for 2024-5 and 2025-6.

    65 . Ministers agreed on the importance of ensuring all children have the right to grow up in a safe and nurturing family environment. Ministers recognised the transformative impact on children’s health, capacity to learn and economic prospects that growing up in a family-based environment can have. Ministers acknowledged the UK’s Global Campaign on Children’s Care Reform and agreed to work together to drive international awareness and demonstrate their commitment to children’s care reform.

    66 . Ministers reiterated their commitment to upholding shared values and continuing to invest in sustainable development, gender equality, disability equity and social inclusion, which underpin global prosperity. To support sustainable development, Ministers agreed to deepen cooperation with emerging donors of development assistance, to diversify funding, enhance development effectiveness, share lessons and build trust and transparency with partners. Ministers committed to work together to deliver sustainable solutions for Small Island Developing States (SIDS), recognising their unique vulnerabilities and to ensure meaningful engagement in international processes, including ODA graduation.

    Media enquiries

    Email newsdesk@fcdo.gov.uk

    Telephone 020 7008 3100

    Email the FCDO Newsdesk (monitored 24 hours a day) in the first instance, and we will respond as soon as possible.

    Updates to this page

    Published 25 July 2025

    MIL OSI United Kingdom

  • MIL-OSI Africa: SA signs US$474.6 million loan for Just Energy Transition

    Source: Government of South Africa

    Friday, July 25, 2025

    South Africa and the African Development Bank (AfDB) have signed a US$474.6 million loan agreement aimed at supporting the implementation of the Just Energy Transition (JET).

    The loan agreement with the AfDB follows the first policy loan concluded in 2023 to support South Africa’s Just Energy Transition. 

    “This new agreement highlights the importance of South Africa’s partnership with the AfDB in advancing South Africa’s development agenda. It strengthens efforts to improve energy security measures, accelerate the decarbonisation of the economy, and enhance the socio-economic benefits of the energy transition enabling inclusive economic growth and fostering job creation,” National Treasury said on Thursday.

    This loan is part of the third Development Policy Operation which includes participation from the World Bank, KFW Development Bank, Japan International Cooperation Agency, and the Organisation of the Petroleum Exporting Countries Fund for International Development (OPEC Fund) to support structural reforms to enhance the efficiency, resilience, and sustainability of the country’s infrastructure services.

    It offers favourable concessional financial terms at a nominal value of US$474.6 million with a maturity of 15 years and a 3-year grace period at an interest rate of a daily Secured Overnight Financing Rate (SOFR) plus 1.22%.

    “The National Treasury wishes to express its appreciation to the AfDB for its continued partnership and support of South Africa’s development objectives. 

    “This includes efforts to implement critical reforms in the energy and transport sectors, while also advancing the country’s Just Energy Transition goals and meeting foreign currency commitments at lower interest rates.” – SAnews.gov.za

    MIL OSI Africa

  • MIL-OSI Russia: Call for Papers: International Conference on Topical Issues in Nuclear Installation Safety

    Translation. Region: Russian Federal

    Source: International Atomic Energy Agency –

    An important disclaimer is at the bottom of this article.

    TIC2026 will bring together nuclear safety regulators, plant designers and operators, technical support organisations and other stakeholders from various countries, as well as international organisations. The aim is to increase knowledge on key topics related to the safety of nuclear installation design, safety assessment, siting, construction, operation and regulation of both existing and new nuclear installations.

    According to the boss IAEA Safety Assessment Sections Ana Gomes, “The Conference will provide a comprehensive forum where nuclear safety stakeholders representing different generations of nuclear projects and a wide range of nuclear safety areas will be able to address a wide range of nuclear safety issues, making it a truly inclusive event.”

    Please note: This information is raw content obtained directly from the source of the information. It is an accurate report of what the source claims and does not necessarily reflect the position of MIL-OSI or its clients.

    .

    MIL OSI Russia News

  • MIL-OSI Africa: Her Excellency (H.E.) Bridget Motsepe-Radebe to Headline WomenIN Festival 2025 as Keynote Speaker

    Source: APO

    The WomenIN (WiN) (www.WeAreWomenIN.com) Festival is proud to announce Her Excellency Bridget Motsepe-Radebe, Chairman & Founder of Mmakau Mining and Ambassador for Economic Development at the Pan-African Parliament, as the official keynote speaker for the highly anticipated WomenIN Festival 2025, taking place from 13–14 November 2025 in Cape Town, South Africa.

    Renowned for her bold leadership, advocacy for gender and economic equality, and trailblazing legacy in the mining sector, H.E. Motsepe-Radebe has consistently broken barriers and redefined power and influence on the continent. Her presence at this year’s festival is set to ignite conversations, inspire generations, and elevate the mission of WomenIN — to connect, empower, and celebrate women across industries and borders.

    “Having H.E. Bridget Motsepe-Radebe headline this year’s WomenIN Festival is a full-circle moment for so many of us,” says Naz Fredericks Maharaj, Director of the WomenIN Portfolio. “She is a living symbol of what it means to lead with both courage and conviction. Her voice reflects the essence of this year’s theme — Limitless. No Labels. No Limits. No Apologies. We are honoured to welcome her to the stage, and even more excited for what her message will unlock in every woman attending this year’s festival.”

    The WomenIN Festival brings together women leaders, entrepreneurs, creatives, and changemakers from diverse sectors including mining, energy, mobility, finance, fashion, media, and the green economy. With a curated program of thought-provoking dialogues, fireside chats, capacity-building sessions, live activations, and power networking, the festival is a movement — not just a moment.

    This keynote announcement marks the first of many exciting speaker and program reveals as the WomenIN team rolls out its boldest edition yet.

    Tickets are officially on sale — reserve your seat and be part of a movement that’s shaking the world:

    Visit www.WeAreWomenIN.com to get your ticket, sponsor someone else’s, or explore partnership opportunities.

    Come as you are. Leave ignited.

    Distributed by APO Group on behalf of VUKA Group.

    Additional Links:
    Website: www.WeAreWomenIN.com
    Link to tickets : https://apo-opa.co/450gy1h

    WomenIN (WiN): Empowering Women, Breaking Barriers, Creating Impact
    WomenIN is a powerful cross-sector movement that connects, inspires, and uplifts women across Africa through collaboration, leadership, and sustainable development. From energy and mobility to retail, gaming, and the green economy, WiN is driving real change by building inclusive ecosystems where women can thrive.

    Through a range of in-person gatherings, digital content, workshops, and sector-specific initiatives, WomenIN provides a trusted platform for female professionals, entrepreneurs, changemakers, and allies to grow together, break silos, and co-create solutions for Africa’s future. With a strong focus on capacity building, leadership development, and market access for female-owned businesses, WomenIN is building a legacy of impact for generations to come.

    Whether you’re a corporate, NPO, SMME, or individual changemaker, there is space for you at the table—because we win when we WiN together.

    For more information, please visit: www.WeAreWomenIN.com or contact our team at info@wearewomenin.com.

    ABOUT VUKA Group:
    VUKA Group brings people and organisations together to connect with information and each other in meaningful conversations that drive growth and transformation across Africa’s industries. With 20+ years of experience on the continent, the group delivers sector-leading platforms across Energy, Mining, Smart Mobility, Transport, Retail, and Women Empowerment.

    The WomenIN (WiN) portfolio is a flagship initiative of VUKA Group, championing gender inclusivity and creating opportunities for women to lead, influence, and innovate across sectors. With a proudly African team and a commitment to sustainable development, VUKA is creating a future where everyone has the opportunity to rise.

    Learn more at: www.WeAreWomenIN.com

    Media files

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    MIL OSI Africa

  • MIL-OSI Russia: The government has suspended floating rates of duties on sunflower oil

    Translation. Region: Russian Federal

    Source: Government of the Russian Federation – Government of the Russian Federation –

    An important disclaimer is at the bottom of this article.

    Resolution of July 24, 2025 No. 1091

    Document

    Resolution of July 24, 2025 No. 1091

    The government is suspending the floating rates of export duties on sunflower oil and sunflower meal. This will increase the volume of shipments to foreign markets and support sunflower producers and processors. This decision was made at the suggestion of the Oil and Fat Union. It is especially relevant in anticipation of autumn field work.

    Floating rates of export customs duties on sunflower oil and meal were established by the Government from 2021 and 2022, respectively, in order to protect the domestic market from unjustified price increases. Thus, it was possible to stimulate the economic interest of producers in maintaining product supplies to the domestic market.

    Currently, the domestic market is fully supplied with sunflower oil. Therefore, the suspension will not affect the availability of sunflower oil for Russians.

    In June 2025, the export duty rate on sunflower oil was 7119.8 rubles per ton. In July – 4739.3 rubles per ton.

    In June 2025, the export duty rate on sunflower meal was 1,244.1 rubles per ton. In July 2025 – 1,054.4 rubles per ton.

    After the adoption of the Government Resolution, the rates were reset to zero. This measure will be in effect until August 31, 2025 inclusive.

    The signed document introduces changes toGovernment Resolution of April 6, 2021 No. 546.

    Please note: This information is raw content obtained directly from the source of the information. It is an accurate report of what the source claims and does not necessarily reflect the position of MIL-OSI or its clients.

    .

    MIL OSI Russia News

  • MIL-OSI Banking: BSTDB Backs Renewable Energy Expansion in Bulgaria and Romania with €40 Million Loan to Renalfa IPP

    Source: Black Sea Trade and Development Bank

    Press Release | 24-Jul-2025

    Joint €315 million international financing to accelerate clean energy investments

    The Black Sea Trade and Development Bank (BSTDB) is providing up to €40 million loan to support the development, hybridization, and expansion of Renalfa IPP’s renewable energy assets in Bulgaria and Romania. The financing forms part of a broader €315 million financing package secured from leading development finance institutions and commercial banks, including the European Bank for Reconstruction and Development (EBRD), Kommunalkredit Austria AG, OTP Hungary, NLB Slovenia, and UniCredit BulBank.

    The funds will enable Renalfa IPP to upgrade its portfolio of renewable energy and battery energy storage systems (BESS), contributing to the decarbonization of Bulgaria’s and Romania’s power systems. The project will help diversify the countries’ energy mix, enhance energy security, and accelerate their transition to low-carbon economies. The BSTDB financing will also help catalyze further private and public sector investments, generate employment during both the construction and operation phases, and create long-term value for local communities. The operation represents a major step forward in the region’s transition toward cleaner, more secure, and sustainable energy systems.

    “This investment marks an important milestone in BSTDB’s efforts to support the clean energy transition in the Black Sea region,” said Dr. Serhat Köksal, BSTDB President.  “By backing the development of solar, wind, and battery storage infrastructure in Bulgaria and Romania, we are strengthening the resilience and competitiveness of their electricity sectors. The operation will play a key role in addressing the countries’ growing energy demands, while also reducing carbon emissions and supporting their commitments to climate goals. Moreover, it aligns closely with BSTDB’s Climate Strategy and reinforces our commitment to financing sustainable infrastructure and regional growth.”

    Ivo Prokopiev, CEO of Renalfa IPP, commented: “The successful raising of growth funding is an important milestone for Renalfa IPP and for our whole group. It proves the competitiveness of our integrated model for developing, investing and operating large hybrid assets. The early implementation of long duration co-located BESS allows Renalfa IPP to start offering green baseload products to market in CEE for the first time. We are proud, together with our partners from RGreen, to be on the frontier of energy transition not only in CEE, but in the whole EU.”

    Renalfa IPP is a leading independent power producer based in Vienna, specializing in the development, construction, and operation of renewable energy projects across Central and Eastern Europe. As an established platform with strong business model capabilities, Renalfa IPP works across the full value chains from project origination to asset operation. The company focuses on solar, wind, and Battery Energy Storage Systems (BESS), supporting the region’s transition to a sustainable and low-carbon energy future. Renalfa IPP is a joint venture between Renalfa Solarpro Group and RGREEN INVEST. 

    Renalfa Solarpro Group is a Vienna based clean energy and e-mobility investment group with a focus on renewable energy generation assets. Renalfa Solarpro is an established platform with strong business model capabilities, working across the full solar PV, wind, and BESS value chains from project origination to asset operation.

    RGREEN INVEST is an independent French mission-driven investment management company committed to helping investors channel their capital towards financing projects dedicated to accelerating the energy transition, mitigation, and adaptation to climate change.

    https://www.renalfa.com

    https://www.rgreeninvest.com

     

    The Black Sea Trade and Development Bank (BSTDB) is an international financial institution established by Albania, Armenia, Azerbaijan, Bulgaria, Georgia, Greece, Moldova, Romania, Russia, Türkiye, and Ukraine. The BSTDB headquarters are in Thessaloniki, Greece. BSTDB supports economic development and regional cooperation by providing loans, credit lines, equity and guarantees for projects and trade financing in the public and private sectors in its member countries. The authorized capital of the Bank is EUR 3.45 billion. For information on BSTDB, visit www.bstdb.org.

     

    Contact: Haroula Christodoulou

    : @BSTDB

    MIL OSI Global Banks

  • MIL-OSI: Stage 8 Presale Live for EVM Layer 2 Meme Coin Little Pepe, With Over $12M Raised in Total

    Source: GlobeNewswire (MIL-OSI)

    DUBAI, United Arab Emirates, July 25, 2025 (GLOBE NEWSWIRE) — Little Pepe (LILPEPE) is redefining what meme coins can accomplish in 2025. Built on an Ethereum Virtual Machine (EVM)-compatible Layer 2 community, this rapidly rising meme token has formally entered stage 8 of its presale. Priced at $0.0017, the latest stage follows a major milestone: over $12 million raised and more than 8.5 billion tokens sold so far. These numbers are turning heads across the crypto area, signaling both strong investor confidence and a brand-new wave of demand for meme coins that blend utility with viral culture.

    While many meme coins rely completely on internet hype and celebrity-pushed buzz, Little Pepe sticks out by way of turning in a scalable infrastructure built for long-term use. Its success in investment rounds and engaged network endorse that it can turn out to be one of the standout meme projects of the year.

    Layer 2 Power Meets Meme Energy

    What makes Little Pepe different is its Ethereum Layer 2 foundation, a crucial advancement that enhances the project’s overall utility and user experience. By operating on a Layer 2 chain, $LILPEPE can offer key benefits such as Lower transaction fees, Faster execution times, Reduced network congestion, and Ethereum-level security

    For users tired of expensive gas fees and slow transactions, Little Pepe’s infrastructure offers a welcome alternative. The EVM compatibility ensures seamless integration with existing Ethereum dApps and tools, increasing accessibility for developers and investors alike.

    This tech-forward approach gives Little Pepe a critical edge. While meme coins are typically seen as speculative, $LILPEPE is being increasingly viewed as a platform in development—a token with the architecture to support real-world applications in the near future.

    Over $12 Million Raised—and Counting

    Little Pepe’s presale has already crossed the $12 million mark, showcasing serious interest from retail and possibly even institutional investors. With each stage offering a higher price, whale investors have already seen the value of their holdings increase, reinforcing confidence in the project’s long-term prospects.

    More than 8.5 billion tokens have been sold, showing rapid and sustained interest as the presale progresses. Unlike many projects that struggle to maintain attention beyond initial hype, Little Pepe is building momentum with each passing week. The pace of this funding also indicates growing demand for Ethereum-based meme coins that offer something more. Investors aren’t just betting on humor—they’re betting on blockchain performance, future integrations, and scalability.

    Stage 8: A Crucial Presale Chapter

    Stage 8 marks a critical moment in the presale journey. At $0.0017, the current token price reflects the project’s rising profile and strong community support. As Little Pepe gets closer to potential exchange listings, this stage may represent one of the final opportunities for whale investors to secure a favorable entry point.

    Interest in Stage 8 is already climbing, mirroring the energy seen in previous rounds. With such a strong funding record and an increasingly global presence, it’s likely that this stage will sell out quickly—especially as the project approaches a broader marketing push and public launch. 

    As presale stages progress, each phase tends to close faster than the last. Investors following the project closely are now eyeing Stage 8 as a key moment to get in before $LILPEPE becomes more widely available.

    About Little Pepe

    Little Pepe is a next-gen Layer 2 blockchain designed to merge meme culture with high-speed, low-cost decentralized infrastructure. Built for scalability, security, and accessibility, Little Pepe supports EVM-compatible applications and is powered by means of the $LILPEPE token. The project’s mission is to create a meme coin environment wherein utility meets virality, empowering users through cutting-edge technology and lightning-fast transactions.

    For more information:

    Website: https://littlepepe.com/

    Telegram: https://t.me/littlepepetoken

    Twitter: https://x.com/littlepepetoken

    Contact Details: COO- James Stephen Email: media@littlepepe.com

    Disclaimer: This content is provided by Little Pepe. The statements, views, and opinions expressed in this content are solely those of the content provider and do not necessarily reflect the views of this media platform or its publisher. We do not endorse, verify, or guarantee the accuracy, completeness, or reliability of any information presented. We do not guarantee any claims, statements, or promises made in this article. This content is for informational purposes only and should not be considered financial, investment, or trading advice.Investing in crypto and mining-related opportunities involves significant risks, including the potential loss of capital. It is possible to lose all your capital. These products may not be suitable for everyone, and you should ensure that you understand the risks involved. Seek independent advice if necessary. Speculate only with funds that you can afford to lose. Readers are strongly encouraged to conduct their own research and consult with a qualified financial advisor before making any investment decisions. However, due to the inherently speculative nature of the blockchain sector—including cryptocurrency, NFTs, and mining—complete accuracy cannot always be guaranteed.Neither the media platform nor the publisher shall be held responsible for any fraudulent activities, misrepresentations, or financial losses arising from the content of this press release. In the event of any legal claims or charges against this article, we accept no liability or responsibility.Globenewswire does not endorse any content on this page.

    Legal Disclaimer: This media platform provides the content of this article on an “as-is” basis, without any warranties or representations of any kind, express or implied. We assume no responsibility for any inaccuracies, errors, or omissions. We do not assume any responsibility or liability for the accuracy, content, images, videos, licenses, completeness, legality, or reliability of the information presented herein. Any concerns, complaints, or copyright issues related to this article should be directed to the content provider mentioned above.

    A photo accompanying this announcement is available at https://www.globenewswire.com/NewsRoom/AttachmentNg/6e74c864-def7-475a-a4cf-261380ce4586

    The MIL Network

  • India successfully tests UAV-Launched Precision Guided Missile in Andhra Pradesh

    Source: Government of India

    Source: Government of India (4)

    In a boost to India’s indigenous defence capabilities, the Defence Research and Development Organisation (DRDO) on Friday successfully conducted flight trials of the UAV-Launched Precision-Guided Missile (ULPGM)-V3 at the National Open Area Range (NOAR) in Kurnool, Andhra Pradesh.

    In a post on X, Defence Minister Rajnath Singh announced the achievement, “In a major boost to India’s defence capabilities, DRDO has successfully carried out flight trials of UAV Launched Precision Guided Missile (ULPGM)-V3 in the National Open Area Range (NOAR), test range in Kurnool, Andhra Pradesh. Congratulations to DRDO and the industry partners, DcPPs, MSMEs and Start-ups for the development and successful trials of the ULPGM-V3 system. This success proves that the Indian industry is now ready to absorb and produce critical Defence Technologies.”

    While detailed specifications of the ULPGM-V3 remain classified, its development reflects a strategic progression in India’s guided missile programme. The earlier ULPGM-V2, developed by DRDO’s Terminal Ballistics Research Laboratory (TBRL), featured multiple warhead configurations. The V3 variant, believed to incorporate advanced features such as imaging infrared (IIR) seekers and dual-thrust propulsion systems, builds on this legacy and was previewed during Aero India 2025.

    The successful trial underscores India’s growing emphasis on unmanned precision-strike capabilities – an essential element of modern warfare. ULPGM systems are designed to be lightweight, highly accurate, and compatible with a range of aerial platforms, offering critical operational flexibility in dynamic combat environments.

    The choice of NOAR in Kurnool for the trial aligns with DRDO’s strategy of leveraging this facility to test advanced technologies. In recent months, the range has hosted successful trials of high-energy laser-based Directed Energy Weapons (DEWs), including systems that neutralized fixed-wing UAVs and swarm drones – highlighting India’s expanding high-tech defence testing infrastructure.

    (IANS)

  • MIL-OSI: BW Energy: Invitation to Q2 2025 and half-year results presentation 01 August 

    Source: GlobeNewswire (MIL-OSI)

    Invitation to Q2 2025 and half-year results presentation 01 August  

    BW Energy will release its second quarter and half-year 2025 results on Friday, 01 August at 07:00 CEST.  

    A conference call followed by Q&A will be hosted by CEO Carl K. Arnet and CFO Brice Morlot the same day at 14:00 CEST. 

    You can follow the presentation via webcast:

    https://events.webcast.no/viewer-registration/qQC1bQEB/register

    Call-in information

    Participants dial in numbers:

    DK: +45 7876 8490
    SE: +46 8 1241 0952
    NO: +47 2195 6342
    UK: +44 203 769 6819
    US: +1 646-787-0157
    Singapore: 65-3-1591097
    France: 33-1-81221259

    Conference code: 980877

    For further information, please contact:

    Martin Seland Simensen, VP Investor Relations BW Energy

    +47 416 92 087, martin.simensen@bwenergy.no

    About BW Energy:

    BW Energy is a growth E&P company with a differentiated strategy targeting proven offshore oil and gas reservoirs through low risk phased developments. The Company has access to existing production facilities to reduce time to first oil and cashflow with lower investments than traditional offshore developments. The Company’s assets are 73.5% of the producing Dussafu Marine licence offshore Gabon, 100% interest in the Golfinho and Camarupim fields, a 76.5% interest in the BM-ES-23 block, a 95% interest in the Maromba field in Brazil, a 95% interest in the Kudu field in Namibia, all operated by BW Energy. In addition, BW Energy holds approximately 6.6% of the common shares in Reconnaissance Energy Africa Ltd. and a 20% non-operating interest in the onshore Petroleum Exploration License 73 (“PEL 73”) in Namibia. Total net 2P+2C reserves and resources were 599 million barrels of oil equivalent at the start of 2025.

    This information is subject to the disclosure requirements pursuant to Section 5-12 the Norwegian Securities Trading Act

    The MIL Network

  • MIL-OSI: BW Energy: Invitation to Q2 2025 and half-year results presentation 01 August 

    Source: GlobeNewswire (MIL-OSI)

    Invitation to Q2 2025 and half-year results presentation 01 August  

    BW Energy will release its second quarter and half-year 2025 results on Friday, 01 August at 07:00 CEST.  

    A conference call followed by Q&A will be hosted by CEO Carl K. Arnet and CFO Brice Morlot the same day at 14:00 CEST. 

    You can follow the presentation via webcast:

    https://events.webcast.no/viewer-registration/qQC1bQEB/register

    Call-in information

    Participants dial in numbers:

    DK: +45 7876 8490
    SE: +46 8 1241 0952
    NO: +47 2195 6342
    UK: +44 203 769 6819
    US: +1 646-787-0157
    Singapore: 65-3-1591097
    France: 33-1-81221259

    Conference code: 980877

    For further information, please contact:

    Martin Seland Simensen, VP Investor Relations BW Energy

    +47 416 92 087, martin.simensen@bwenergy.no

    About BW Energy:

    BW Energy is a growth E&P company with a differentiated strategy targeting proven offshore oil and gas reservoirs through low risk phased developments. The Company has access to existing production facilities to reduce time to first oil and cashflow with lower investments than traditional offshore developments. The Company’s assets are 73.5% of the producing Dussafu Marine licence offshore Gabon, 100% interest in the Golfinho and Camarupim fields, a 76.5% interest in the BM-ES-23 block, a 95% interest in the Maromba field in Brazil, a 95% interest in the Kudu field in Namibia, all operated by BW Energy. In addition, BW Energy holds approximately 6.6% of the common shares in Reconnaissance Energy Africa Ltd. and a 20% non-operating interest in the onshore Petroleum Exploration License 73 (“PEL 73”) in Namibia. Total net 2P+2C reserves and resources were 599 million barrels of oil equivalent at the start of 2025.

    This information is subject to the disclosure requirements pursuant to Section 5-12 the Norwegian Securities Trading Act

    The MIL Network

  • MIL-OSI China: China sets up state-owned fusion energy company

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

    This photo taken on March 9, 2025 shows the one-eighth vacuum chamber and overall installation system, one of the key subsystems of the Comprehensive Research Facility for Fusion Technology (CRAFT), in Hefei, capital of east China’s Anhui Province. [Photo/Xinhua]

    China has set up a state-owned fusion energy company in its latest drive to commercialize fusion power, aiming to harness an almost inexhaustible source of clean energy.

    China Fusion Energy Co. Ltd (CFEC), a subsidiary of the China National Nuclear Corporation (CNNC), was unveiled in Shanghai this week with a registered capital of 15 billion yuan (about 2.1 billion U.S. dollars).

    The newly-founded firm, positioned as an innovation driver for advancing China’s fusion engineering and commercialization, is tasked with developing platforms for technological research and capital operations, the CFEC said.

    China announced prioritized support for core future energy technologies in 2024, with a focus on nuclear fusion, in a bid to fast-track the transition of this cutting-edge technology from the lab to practical application.

    Shanghai is doubling down on its nuclear ambitions, striving to build a world-class hub for nuclear equipment manufacturing and advanced fusion research and development, while securing double-digit annual growth for its nuclear power sector through 2025.

    China Fusion Energy signed a cooperation agreement for a fusion innovation consortium with Shanghai Jiao Tong University, China Electrical Equipment Group, Shanghai Electric and Shenergy Group. Many of these local heavyweights in the traditional power generation sector are poised to secure market share in upstream and downstream fusion-related equipment.

    CITIC Securities estimates that the global nuclear fusion device market could reach a scale of 2.26 trillion yuan between 2030 and 2035.

    In March, a team from Energy Singularity in Shanghai achieved a breakthrough in high-temperature superconducting tokamak technology, with their magnet surpassing the previous record set by the Massachusetts Institute of Technology and Commonwealth Fusion Systems in the United States.

    This Shanghai startup has announced a plan to complete its next-generation tokamak by 2027, targeting a 10-fold energy gain, a critical milestone for commercial fusion viability.

    In addition to the eastern Chinese manufacturing hub, two inland provinces in China have significantly expanded scientific research and investment in the fusion energy sector.

    East China’s Anhui Province is actively constructing the Burning Plasma Experimental Superconducting Tokamak (BEST) in its capital Hefei, which is expected to demonstrate fusion electricity generation for the first time in history.

    The massive facility, an upgraded version of the record-breaking Experimental Advanced Superconducting Tokamak currently operational at a research institute in the city, is also expected to be completed by 2027.

    Fusion Energy Tech., the Hefei-based company building the BEST, is another large firm with majority state-owned capital stakes and a registered capital of 14.5 billion yuan. Chinese automaker NIO is one of its major shareholders.

    Engineers there are aiming to construct a fusion engineering demonstration reactor, based on the BEST project. Commercial operations are projected to start somewhere between 2040 and 2050.

    Separately, research and commercial entities in southwest China’s Sichuan Province are exploring various technical routes to harvesting fusion energy, including tokamak, linear field-reversed configuration (FRC), inertial confinement and magnetically driven fusion.

    Last Friday, a Chengdu-based fusion startup achieved plasma ignition in its FRC device, the HHMAX-901, marking a significant milestone toward scaling the technology for commercial use. Similarly, U.S.-based Helion Energy plans to adopt this approach and is expected to begin supplying power to Microsoft by 2028.

    Earlier this month, the Sichuan provincial government released its plan to support the development of “controlled nuclear fusion” as a future industry.

    A recent analysis by MIT Technology Review suggests that China’s robust industrial base could allow its emerging fusion energy sector to “climb the learning curve much faster and more effectively” than its global competitors.

    China’s industrial might in thin-film processing, large metal-alloy structures and power electronics provides a strong foundation to establish the upstream supply chain for fusion, according to the article.

    The journal specifically highlighted China’s strengths in large-scale power electronics, which are also used in similar systems such as high-speed rail and renewable microgrids.

    Zhou Lisha, a researcher at the China Enterprise Reform and Development Society, noted that the establishment of CFEC will boost the sector’s technical and innovation capabilities, and propel the rapid development of the “artificial sun” industry.

    Despite its promising prospects, CNNC, CFEC’s parent company, has cautioned that controlled nuclear fusion is still in the developmental stage, with uncertainties and even risks of commercial failure.

    MIL OSI China News

  • MIL-OSI USA: Sen. Markey and Rep. Kamlager-Dove Announce Legislation to End Solitary Confinement in Federal Detention Facilities

    US Senate News:

    Source: United States Senator for Massachusetts Ed Markey

    Over 120,000 people are held in solitary confinement in the United States

    Bill Text (PDF)

    Washington (July 24, 2025) – Senator Edward J. Markey (D-Mass.) and Representative Sydney Kamlager-Dove (CA-37) today announced the reintroduction of the End Solitary Confinement Act, legislation that would end solitary confinement in federal prisons, jails, and detention centers, with limited exceptions. This bill would create minimum standards for incarceration, including by requiring that facilities give detainees access to out-of-cell interaction and recreation and by capping the length of solitary confinement at four hours.

    Solitary confinement has many different names, including “restrictive housing” in Massachusetts. Individuals held in solitary confinement can be isolated in a small, concrete, windowless cell for 22 hours or longer. Placement in solitary for any length of time, whether days or even hours, can cause severe, long-term harm. Individuals held in solitary confinement may suffer serious adverse effects on their mental and physical health, including an increased risk of suicide, heart disease, anxiety, and depression. Solitary confinement is also disproportionately inflicted on Black, Brown, and LGBTQ+ individuals, as well as on vulnerable populations, including persons with preexisting mental health illnesses.

    “Solitary confinement is a cruel and unnecessary practice that has no place in our country. This practice isn’t rehabilitation, it’s torture,” said Senator Markey. “Forcing people, including those from vulnerable groups, into small, cramped, concrete prison cells without human interaction for hours, days, weeks, and even months on end is inhumane. I am proud to introduce this legislation, alongside Representative Kamlager-Dove, to move us closer to ending solitary confinement, once and for all.”

    “Solitary confinement is torture, period,” said Congresswoman Kamlager-Dove. “This outdated practice, dating back to the 1800s, does nothing to promote rehabilitation. Research consistently shows it causes severe mental health issues, intensifies existing barriers to recovery, and disproportionately harms incarcerated Black, Brown, and LGBTQ+ individuals. We must abolish solitary confinement entirely—and I’m proud to lead the charge with this bill that will finally end its use in the United States.”

    Cosponsors in the Senate include Senators Elizabeth Warren (D-Mass.), Bernie Sanders (I-Vt.), and Jeff Merkley (D-Ore).

    This legislation is endorsed by the American Civil Liberties Union, Center for Constitutional Rights, Vera Institute of Justice, National Religious Campaign Against Torture, Unlock the Box Campaign, the #HALTsolitary Campaign, and Zealous.

    Specifically, the End Solitary Confinement Act would:

    • End solitary confinement in federal prisons, jails and other detention settings with limited exceptions, including a 4-hour maximum for emergency de-escalation;
    • Protect vulnerable populations, including elderly individuals and pregnant persons, from placement in solitary confinement;
    • Ensure detainees have meaningful access to out-of-cell time, group programming, and basic needs and services;
    • Impose strict due process protections, including access to representation and neutral decision-makers;
    • Create oversight and enforcement mechanisms, including mandatory reporting, a private cause of action, oversight by a community monitoring body, and enhanced media access; and
    • Incentivize states and municipalities to adopt similar bans on solitary confinement.

    Senator Markey has worked consistently to reform prison practices and provide resources to formerly and currently incarcerated people. Senator Markey and Senator Amy Klobuchar (D-Minn.) introduced the Fair Chance Jobs Month Resolution in May 2025, to ensure that formerly incarcerated individuals have a fair chance at securing good-paying, stable employment. In February 2024, Senator Markey sent a letter to then-Secretary of Energy Jennifer Granholm urging the Department of Energy (DOE) to make good-paying clean energy jobs accessible to currently and formerly incarcerated people.

    MIL OSI USA News

  • MIL-Evening Report: What makes a song ‘Australian’? Triple J’s Hottest 100 reignites a bigger question of national identity

    Source: The Conversation (Au and NZ) – By Catherine Strong, Associate Professor, Music Industry, RMIT University

    On July 26, Triple J will broadcast the Hottest 100 Australian Songs, as voted by the public. While predictions for winners and even preemptive complaining about the shortlist are taking up column space and social media posts, there is an underlying question: what we mean when we talk about “Australian songs”?

    Do these songs sound a particular way? Do they express something about what it means to be Australian? Or is it purely about where the artist was born?

    Importantly, how will each of these factors influence voting?

    Can a song sound Australian?

    Musical cultures with their own unique sounds have existed on this continent for tens of thousands of years. The sound of the didgeridoo is often used as a shorthand to signify Australianness in films, television and, to a lesser extent, popular songs.

    However, the history of dispossession and genocidal practices that have accompanied settlement in Australia means much has been lost from these musical traditions. Indigenous performers have been actively excluded from the same music-making spaces where other songs we think of as “Australian” have been created.

    Since British colonisation in the late 18th century, Australian music has also been part of global music flows. Settlers arrived with songs and musical influences from their own cultures. Jazz, country, rock and pop inspired local versions of these genres.

    But is there anything truly Australian about such music, or is it just imitation? And this conundrum connects to wider issues of Australia’s identity debated during the 20th century: was it a country, or still just a colony?

    Back in the 1970s, this question was also on then prime minister Gough Whitlams’s mind. After his election in 1972, Whitlam gave a huge boost to funding for cultural and creative activities to “help establish and express an Australian identity through the arts”, as part of a suite of nation-building activities.

    Building the pub rock canon

    The dirty guitar sounds of the pub rock scene of the 1970s, with its associated subcultures, are sometimes said to be Australia’s first distinct offering in post-rock ‘n’ roll music.

    This was followed by the rise of bands such as Midnight Oil and Cold Chisel, who found success not just by drawing on more local sounds, but also by referencing Australian places, politics and cultures.

    The Whitlam government’s broadcasting reforms meant this music had homes on community radio and the new youth station 2JJ (now Triple J).

    The bands from this era have come to make up what might be described as the Oz rock canon – a collection of works seen to make up the “best” of the art form. Canons exert a strong influence over how we assess music, meaning these bands will probably appear in the tomorrow’s countdown.

    This idea of the rock canon is almost perfectly reflected in the ten entries by Prime Minister Anthony Albanese to tomorrow’s countdown. His selection of almost 100% white male musicians encapsulates the exclusionary nature rock of this period.

    The fact that our last two prime ministers, despite being from opposite sides of politics, produced very similar lists, gives us insight into the persistence of this canon, and what ideas about “Australian culture” circulate in the halls of power.

    It’s questionable whether any of the bands or songs on Albanese’s list could be said to have a coherent “Australian” sound, yet they have come to hold a place in the national imagination.

    Changing canons and new sounds

    Triple J’s Hottest 100 of All Time in 2009 was seen as a surprising recapitulation of the (male) rock canon, especially given the station’s otherwise diverse playlists.

    However, the highest-placed Australian song on the list was The Nosebleed Section by Hilltop Hoods, representing the recent and rapid rise of Aussie hip-hop.

    The 2011 Hottest 100 Australian Albums of All Time (the closest forerunner to the current poll) further updated the canon, with Powderfinger’s Odyssey Number Five (2000) in the top spot, and other top ten entries by electronic groups The Presets and The Avalanches.

    Nonetheless, the canon remained male dominated, with the highest woman-fronted album being Missy Higgins’s The Sound of White (2004) at number 29.

    The past decade has seen a boom in Indigenous representation on Australian airwaves and stages, with artists such as Thelma Plum, Barkaa, A.B. Original and Baker Boy.

    These artists use a range of genres and styles to express pride in their Indigeneity, and critique Australian identity. A.B. Original’s song January 26 was number 17 in 2016’s Hottest 100 countdown. This was also the last year Triple J chose this date for its annual broadcast, speaking to the power of music to reflect – and even inform – popular sentiment.

    Given recent national debates, a strong contender for the upcoming poll is Treaty (Radio Mix) by Yothu Yindi (which ranked number 11 of all time in 1991). These shifts show how canons can be unsettled over time.

    What if we don’t all agree?

    Recently, Creative Australia came under fire for trying to stifle Khaled Sabsabi’s politically-informed art in the interests of “social cohesion”.

    But others pointed out art provides crucial space for challenging prevailing ideas, and that social cohesion in a democracy is not about reaching complete agreement, but being able to handle disagreement.

    A Hottest 100 that reflects the diversity and even the tensions in Australian society may provoke arguments, but it is in these spaces that we can reflect on what it means to live on these lands.

    Ben Green receives funding from the Australian Research Council and the Australasian Performing Right Association.

    Catherine Strong does not work for, consult, own shares in or receive funding from any company or organisation that would benefit from this article, and has disclosed no relevant affiliations beyond their academic appointment.

    ref. What makes a song ‘Australian’? Triple J’s Hottest 100 reignites a bigger question of national identity – https://theconversation.com/what-makes-a-song-australian-triple-js-hottest-100-reignites-a-bigger-question-of-national-identity-261560

    MIL OSI AnalysisEveningReport.nz

  • MIL-OSI USA: Rep. Mike Levin Introduces Bill to Combat Microfiber Pollution

    Source: United States House of Representatives – Representative Mike Levin (CA-49)

    July 24, 2025

    Bicameral Legislation Would Prevent Microfibers from Our Clothes Entering Our Waters & Bodies

    Washington, D.C.—Today, Rep. Mike Levin (CA-49) introduced the Fighting Fibers Act, which would direct the Environmental Protection Agency (EPA) and Department of Energy (DOE) to require the installation of a microfiber filtration system on new washing machines to address microfiber pollution and health impacts from clothing. A companion bill in the Senate was introduced by Sen. Jeff Merkley of Oregon.

    Scientists estimate millions of tons of microfibers from clothing enter our water systems and oceans every year, making textiles the largest known source of microplastic pollution. Synthetic microfibers, found in clothing containing polyester, shed while being washed due to the friction and turbulence in the washing machine. Once in our waters, microfibers absorb and release toxins that harm wildlife and ultimately contaminate the food that we eat.

    The Fighting Fibers Act would require washing machines sold in the U.S. to include a filter that would prevent microfibers in clothing from shedding into wastewater and eventually contaminating rivers, lakes, and oceans.

    “Microfibers pose a serious threat to our waterways, oceans, and food supply and can ultimately end up in our bodies leading to serious health complications. Preventing them from entering our ecosystems is important to health and safety,” said Rep. Levin. “This bill provides a simple, targeted solution that offsets the environmental and health impacts of microfibers by stopping them in laundry cycles before they can enter our waters and bodies. I thank Sen. Merkley for his partnership on this bill, and I look forward to advancing it through the legislative process.”

    “When it comes to plastics, most of us have been taught the three Rs: reduce, reuse, and recycle. The sinister reality is the three Bs: buried, burned, and borne out to sea, as dangerous chemicals poison our soil, air, and water,” said Sen. Merkley. “Microplastic pollution harms human health and our environment, and the Fighting Fibers Act is a simple fix to help consumers address the pollution from their clothes that is driving our global plastics crisis.”

    “Microfibers are the most common type of microplastic pollution in our ocean and environment and have made their way everywhere from our drinking water to our blood streams. The scale and urgency of this crisis demand immediate action, and adding microfiber filters to washing machines is a common-sense and cost-effective solution available today to address this crisis. We applaud Senator Merkley and Representative Levin for championing the Fighting Fibers Act of 2025 to protect our ocean and our communities from dangerous microplastics,” said Dr. Anja Brandon, Director, Plastics Policy, Ocean Conservancy.

    ###

    MIL OSI USA News

  • MIL-OSI USA: Murphy, Trahan Reintroduce Legislation to Codify College Athletes’ Unrestricted Right to Their Name, Image, Likeness

    US Senate News:

    Source: United States Senator for Connecticut – Chris Murphy

    July 24, 2025

    WASHINGTON—U.S. Senator Chris Murphy (D-Conn.), a member of the U.S. Senate Health, Education, Labor and Pensions Committee, and U.S. Representative Lori Trahan (D-Mass.-03), a member of the U.S. House Committee for Energy and Commerce and a former college athlete, on Wednesday reintroduced legislation that would establish an unrestricted federal right for college athletes to market their Name, Image, and Likeness (NIL). The College Athlete Economic Freedom Act allows international college athletes to market their NIL without losing their visa status, encourages negotiation between athletes and their colleges for the use of athletes’ NIL for promotion and media rights deals, and ensures colleges and collectives do not discriminate on the basis of gender, race, or participating sports in the facilitation of NIL deals.

    “College athletes dedicate years of their lives to their craft and deserve their fair share of a multibillion-dollar industry built on their hard work,” said Murphy. “While the past four years of Name, Image, and Likeness (NIL) policy have allowed these athletes to finally make money off their talent, the NCAA is hoping Donald Trump and Republicans in Congress will help them undo years of hard-earned progress. Our legislation shields college athletes from an assault on their livelihoods by expanding and codifying their basic right to be fairly compensated for their Name, Image, and Likeness.”

    “Instead of trying to undo the rights college athletes fought for decades to secure, Congress should address the real issues facing college sports today,” said Trahan. “The College Athlete Economic Freedom Act codifies athletes’ unrestricted NIL rights nationwide, closes the loophole prohibiting international athletes from entering into NIL agreements, and guarantees that women have a fair shot in the NIL marketplace. It’s long past time for Congress to stand with the athletes who’ve driven this industry without a real seat at the table.”

    Specifically, the College Athlete Economic Freedom Act would:

    • Establish an unrestricted federal right for college athletes and prospective college athletes to market the use of their name, image, and likeness — individually and as a group — by prohibiting colleges, conferences, and the NCAA from setting or enforcing rules that restrict this right or otherwise colluding to limit how athletes can use their NIL
    • Protect athletes’ ability to retain representation as they see fit, including lawyers, agents, and collective representatives (i.e. players associations) while prohibiting the NCAA or conferences from regulating athlete representation
    • Ensure colleges and affiliated NIL collectives do not discriminate by gender, race, or sport in the facilitation of NIL deals along with requiring collectives to register with the Federal Trade Commission (FTC) and report the NIL deals they have facilitated so athletes and stakeholders asserting discrimination have all the information they need to address it
    • Ensure equitable opportunities for college athletes to market their NIL by asserting that institutional support by colleges, conferences, or the NCAA for NIL opportunities is made available to all college athletes, along with commissioning a market analysis of NIL monetization with recommendations for improving opportunities across race, gender, and sport
    • Allow international college athletes to market their NIL in the same ways their non-immigrant peers can without losing their F-1 visa status, including in the case that athletes become employees of their schools and/or athletic associations
    • Require colleges and athletic associations to obtain a group license from athletes for using their NIL for any type of promotion, including via a media rights deal, and notify athletes of how their NIL was used along with how much revenue those deals generated, helping athletes negotiate with colleges, conferences, and the NCAA for their fair share of the revenues they produce
    • Assert robust enforcement for violations by colleges, conferences, or the NCAA in restricting athletes’ NIL rights, notably through asserting per se antitrust penalties, a private right of action for athletes to pursue civil action against violators, and authorizing the Federal Trade Commission (FTC) to levy “unfair or deceptive practice” penalties.

    Full text of the bill is available here.

    A one-pager of the bill is available here.

    MIL OSI USA News

  • MIL-OSI United Kingdom: Development Minister sets out new UK approach to development at G20 meeting in South Africa

    Source: United Kingdom – Executive Government & Departments

    Press release

    Development Minister sets out new UK approach to development at G20 meeting in South Africa

    The UK is resetting its relationship with countries in the Global South and helping countries exit the need for aid, as Baroness Chapman attends the G20 Development Ministerial Meeting in South Africa.

    • Development Minister Baroness Chapman will reset the UK’s approach to international development at the G20 Development Meeting in South Africa today (Friday, 25 July).
    • Economic development underpins the UK’s new approach, as the Minister visits a South African food producer supported by the FCDO’s development arm BII.
    • The UK is supporting countries to transition from traditional aid to innovative financing for development, as the Minister visits a centre for survivors of gender-based violence funded by both the UK and the private sector.

    The UK is resetting its relationship with countries in the Global South and helping countries exit the need for aid, as Baroness Chapman attends the G20 Development Ministerial Meeting in South Africa today (Friday 25 July 2025).

    This follows the publication of ODA allocations earlier this week (Tuesday 22 July 2025), which indicate how the UK is going to spend its aid budget for the next year.

    The UK will move from being a donor to a genuine partner and investor, ensuring every pound spent on aid delivers for the UK taxpayer and the people we support.

    Economic development underpins the UK’s new approach, to help countries grow fairer, more resilient economies and ultimately exit the need for aid, in support of the government’s Plan for Change.

    The Minister saw this in action yesterday (Thursday 24 July 2025) as she visited an Agristar farm which produces macadamia nuts in Mbombela, eastern South Africa. British International Investment (BII), the UK’s development finance institution, is supporting Agristar to expand – supporting jobs and growth and helping to stock British supermarket shelves. 

    The Minister also visited a UK supported care centre for survivors of gender-based violence in Mbombela, alongside South African Minister for Women, Youth and Persons with Disability, Sindisiwe Lydia Chikunga. The centre is supported by a multi-donor fund which has seen increased backing from South African and international private investors. The innovative funding approach has supported over 200 community-based organisations in South Africa working to prevent violence in schools and communities and provide response services for survivors of gender-based violence. This demonstrates the UK and South Africa’s shared commitment to gender equality and women’s empowerment.

    By mobilising private finance and empowering partners to take charge of their own development, the UK is moving away from a paternalistic approach to aid.

    Minister for Development, Baroness Chapman said:

    We want to help countries move beyond aid. In South Africa, I’ve seen the impact we can have with genuine partnerships, rather than paternalism. Our work is supporting jobs and generating global economic growth – and bringing high quality South African produce to UK shops. 

    At the G20 in South Africa, I have one simple message: the world has changed and so must we. The UK is taking a new approach to development, responding to the needs of our partners and delivering real impact and value for money for UK taxpayers.

    At the G20, the Minister is due to discuss the UK’s new approach to international development with counterparts from Egypt, India and Germany.

    The Agristar farm in Mbombela, which the Minister visited yesterday, has benefitted from UK investment as part of the Just Energy Transition Partnership (JETP). BII support has enabled the macadamia nut producer to expand its operations across Africa, invest in measures to mitigate climate risks, and support nearly 400 jobs. BII is also supporting Agristar’s expansion into Malawi.

    BII, which aims to make a return on its investments, has so far supported 92 companies in South Africa and over 35,000 jobs.   

    Its success highlights how the UK’s investment in international development is driving green growth and jobs, boosting global prosperity and stability to help create the conditions to deliver the government’s Plan for Change at home.   

    The Minister will also announce today a new £2 million commitment to support local agribusiness projects by partnering with South African investment funds to drive more private finance for the farming sector.

    In G20 talks on tackling illicit financial flows, the Minister will highlight how money and assets siphoned away as part of criminal activity deprive lower-income countries of vital resources which could otherwise support growth and development. The Foreign Secretary is leading a campaign against illicit finance, mobilising the best UK expertise and international partnerships, so dirty money has nowhere to hide. This is also vital to deterring threats to the safety and security of Britain, as part of the government’s Plan for Change.

    Media enquiries

    Email newsdesk@fcdo.gov.uk

    Telephone 020 7008 3100

    Email the FCDO Newsdesk (monitored 24 hours a day) in the first instance, and we will respond as soon as possible.

    Updates to this page

    Published 25 July 2025

    MIL OSI United Kingdom

  • MIL-OSI USA: July 24th, 2025 Heinrich Criticizes Trump Administration for Working to Stall Energy Projects and Raise Costs on Families

    US Senate News:

    Source: United States Senator for New Mexico Martin Heinrich

    WASHINGTON — During a U.S. Senate Energy and Natural Resources Committee hearing on energy demand growth, U.S. Senator Martin Heinrich (D-N.M.), Ranking Member of the Committee, pressed Jeff Tench, Executive Vice President of Vantage Data Centers and Rob Gramlich, CEO and Founder of Grid Strategies LLC, on Trump Administration actions that are impacting grid reliability and driving up families’ energy costs.

    VIDEO: U.S. Senator Martin Heinrich (D-N.M), Ranking Member of the U.S. Energy and Natural Resources Committee questions Jeff Tench, Executive Vice President of Vantage Data Centers and Rob Gramlich, CEO and Founder of Grid Strategies LLC.

    On the Trump Administration Adding Burdensome Red Tape to Clean Energy Project Approvals

    Senator Heinrich began by asking Jeff Tench, Executive Vice President of Vantage Data Centers, how the Trump Administration adding additional reviews and red tape impacts businesses and grid reliability, “So Mr. Tench, you may be aware, the Department of the Interior recently released a memo that’s going to require the Secretary to review all wind and solar projects on federal lands. It adds just one more layer of red tape. Do you have opinions on what the potential business impacts of energy projects just being delayed in that regulatory process? How that further delays impact the business prospect?”

    Tench responded, affirming that new directives from the Trump Administration will negatively impact business and adding new generation to the grid, “Our observation and our requirement is for more electrons, as you called out in your opening remarks, Vantage is relatively agnostic as to the source of those electrons. So, in the case of rule making or regulatory action that slows down the process of approving new generation or new transmission, would definitely be a negative for our business.”

    Heinrich followed up, “Should in the, in the sort of five-year window like 2025 to 2030, shouldn’t we be focused on putting as many electrons, agnostic of generation source, on the grid as possible to be able to meet the kind of demand that you represent?”

    Tench answered, “Yes, our position is that efforts to move electrons around through enhanced transmission is important, necessary, but insufficient relative to the overall demand. We need more energy, more generation, and more generation, and we need more transmission independent of source. That said, it does need to be a reliable, grid dispatchable source, which I believe, you know, can be accomplished with the right combination of energy source for generation and energy storage.”

    Heinrich responded, alluding to the Trump Administration’s recent reckless actions that stall projects despite growing energy demands, “You know, one of my concerns is we have we have an existing pipeline that is the result of decisions that have been made over the course of the last decade. That pipeline is 95% clean energy plus storage. It’s about 5% gas. You know, a year or two ago, we had a couple of nuclear plants come online, which are great. I support that, but that’s kind of a one off. You know, in the next five years, if we start building new nuclear today, whether that’s SMRs or traditional light water reactors, that’s going to take longer than the five-year window. If I order a combined cycle natural gas turbine today, it’s probably going to come on the grid in 2032 2033 if we’re lucky. So, if you don’t allow the existing projects that are in the queue today, that are our renewables plus storage. What does that do to the price pressure on the grid? What’s the impact of that?”

    Tench answered, “As it relates to price pressure, I’ll probably defer to Rob on that question as more of a grid expert, but in the broader context, our goals are to encourage speed of change in regulatory process, to bring more electrons on the grid. And again, depending upon the site in which we’re developing, our access to proximate energy sources varies, and we are being very pragmatic about how we approach that and make available to ourselves whatever we can in order to meet the demand.”

    Heinrich followed, “Mr. Gramlich, do you want to address the price pressure issue?”

    Gramlich, CEO and Founder of Grid Strategies LLC, answered, confirming that the Administration’s actions to limit new generation is raising costs on consumers, “Sure. I mean, basically it’s supply and demand. There’s scarcity of generation. So, anything that is limiting new generation from coming on, whether it’s interconnection queues, permitting hold ups that Interior, or anything else that’s cutting off supply, and that is definitely raising prices. And we are seeing prices go up wholesale power prices are going up. That is required. Those higher costs are required to be incorporated by state public utility commissions into retail bills. So, retail consumers…”

    Heinrich intervened, “Are there places where prices have actually come down in recent years that you can point to and what was the reason why those prices came down?”

    Gramlich answered, “Sure. Well, I mean, if you just look at, say, the supply stack for some places like Texas. Texas, just over the last couple of days, has had a majority of their peak demands, not just, you know, overnight, not just winter peak, afternoon air conditioning, driven demand served by a majority renewables plus storage.”

    Heinrich pressed, “And were there rolling blackouts?”

    Gramlich answered, “There were not. Reliability. Reliability is better? Yeah, you probably heard about rolling blackouts in California, like five years ago. Honestly, they got behind on resource adequacy. But what did they do? They built a lot of solar and batteries. So same dynamic there. I’m sure we’re seeing a majority renewable energy. Any hour now it’s going to kick in, and then when the air conditioning load this afternoon is high, there’s going to be solar and then the sun will set, air conditioning load will still be high, but the batteries will then kick in and serve through the evening. So again, they don’t do everything.”

    On How the Trump Administration is Raising Families’ Electricity Costs

    Heinrich asked Gramlich, “One of the things we have to deal with here is these agencies and the role that they play in permitting new generation and transmission. So Mr. Gramlich, if, if our permitting agencies, for example, the Department of the Interior, which has added this new level of red tape stall or slow walk permits for generation projects, which we’re currently seeing, and those permit projects, as a result, don’t get on the grid, or they get on the grid slower. What’s the impact to people who pay retail electric prices?”

    Gramlich replied, testifying to how the Trump Administration is raising energy costs on consumers as a result of recent directives, “Sure. Well, obviously that will raise prices. And what’s happening is, you know, love it or hate it, many utilities with their state regulators have put in place plans for the next few years how they’re going to meet load. There might be retirements. There might be load growth. They routinely go through these plans. And just the reality is, it’s largely wind, solar and storage that are in those plans.”

    Heinrich followed, “About 95% in most cases.”

    Gramlich agreed, “Right.”

    Heinrich continued, “So if you take that 95% out, even some portion of it, say a third, what are you going to replace it with in year one, two or three, nothing.”

    Gramlich replied, “Curtailment.”

    Heinrich followed, “Curtailment, exactly. Exactly. Why I say capacity factors is because I’m an engineer, and I don’t remember a lot of the terms, the buzzwords that we get thrown at around a lot here now: firm, baseload, dispatchable. What I remember from my education is capacity factors, right? And if you look at generation today, you know, I have wind in my state that has a 40% capacity factor. It’s not perfect, but it’s pretty darn good. You know, what else has a 40% capacity factor, Mr. Gramlich? Coal today in the United States of America. Everybody says it’s firm and base load, and it’s not. It’s not because it’s expensive and it’s unreliable, and when you have a coal fire generating station go down, the whole thing goes down. Doesn’t go down 3%, it doesn’t go down 10% — you lose that generation until that thermal plant is back up and running. So, in your testimony, you talked about the increase in demand over time. DOE also is predicting a similar amount, about 2% a year, but they’re also claiming that there is somehow 100-fold increased risk of outage, and this relates to capacity factor issue. If forecasted retirements occur between now and 2030, as predicted, what were the assumptions that went into that, that were baked into that claim?”

    Gramlich answered, “Yeah, I think the Department of Energy, I mean, they provided useful analysis with this, this report, but I think they’ve vastly overstated the retirements of generation. And as I said earlier, we have processes, either through utility planning or market to you know, to discourage or prevent retirements, and that’s happening. But also on the supply addition side, there’s a lot more generation out there that could come onto the grid, and I think the Department of Energy study understated that new supply. So, if you understate supply, overstate retirement, suddenly you have a reliability crisis. But it might just be manufactured by those numbers.”

    Heinrich continued, “Yeah, we certainly haven’t seen that in New Mexico, and we haven’t seen that next door in Texas, where they have a totally separate grid from ours, but they’re bringing on lots of new sources of generation, lots of new solar and batteries in particular. You know, transmission lines are such an important piece of all this, because they do help us wield power around the country, and it’s hard to build transmission. It’s why we need to actually do permitting reform, which this Committee did last Congress but hasn’t done this Congress yet. You know, I worked on one transmission line for 17 years of my life, and today it is has facilitated, you know, tens of billions of dollars of economic output. It’s facilitated the largest renewable project in the continent’s history. But it wasn’t easy to get that done if you create a system where the politics can change overnight, where, for example, a loan from the Loan Program Office can be decided by politics rather than by metrics. What is the impact of that on reliability and on price pressure?”

    Gramlich answered, “Well, I mean, so many utilities have testified before this Committee over the years about the need for stability. They’re making 60-year investments, six zero, and if the policies change 180 degrees every four years, they simply can’t do that. So the point is well taken. We need some stability. I do think FERC is a great place for a lot of these orders as a bipartisan, non-partisan agency for permitting. They could do more in that regard, and but we need, we need to get that regulatory stability for investment.”

    MIL OSI USA News

  • MIL-OSI: Athabasca Oil Announces 2025 Second Quarter Results Highlighted by Strong Operational Results, Continued Share Buybacks and a Pristine Financial Position

    Source: GlobeNewswire (MIL-OSI)

    CALGARY, Alberta, July 24, 2025 (GLOBE NEWSWIRE) — Athabasca Oil Corporation (TSX: ATH) (“Athabasca” or the “Company”) is pleased to report its second quarter results marked by strong operational performance, consistent financial results and execution on return of capital commitments. With low corporate break-evens, differentiated long-life assets and a pristine balance sheet, the Company is well positioned to advance its strategic priorities.

    Q2 2025 Consolidated Corporate Results

    • Production: Average production of 39,088 boe/d (98% Liquids), representing 4% (15% per share) growth year-over-year.
    • Cash Flow: Adjusted Funds Flow of $128 million ($0.25 per share). Cash Flow from Operating Activities of $101 million. Free Cash Flow of $66 million from Athabasca (Thermal Oil).
    • Capital Program: $73 million total capital expenditures including $54 million at Leismer to support the 40,000 bbl/d phased growth project.
    • Shareholder Returns: Purchased 24 million shares through its buy-back program year-to-date. The Company is committed to returning 100% of Free Cash Flow (Thermal Oil) to shareholders in 2025 and has completed ~$600 million in share buybacks since March 31, 2023, reducing its fully diluted share count by 21%.

    Operations Highlights

    • Leismer: Production currently ~28,000 bbl/d (June 2025) with four sustaining well pairs expected to be placed on production through the balance of the year. The progressive growth project remains on time and on budget. The Company expects production to stay flat until the next growth plateau of 32,000 bbl/d in H2 2026.
    • Hangingstone: Production currently ~8,900 bbl/d (June 2025) following the start-up of two extended reach well pairs which are outperforming management’s expectations. The asset continues to deliver meaningful free cash flow generation.
    • Duvernay Energy (“DEC”): A four well pad (30% working interest) with ~5,000 meter laterals was completed in mid July and will be placed on production in August. Completion operations are expected to commence on a three well pad (100% working interest) in September. DEC is positioned for strong operational momentum into year end with an exit target of ~6,000 boe/d.

    Resilient Producer

    • Pristine Financial Position: The Company has a Net Cash position of $119 million, Liquidity of $437 million (including $304 million cash) and a long-dated maturity of 2029 on its term debt. The Company also has $2.2 billion of tax pools (~80% high-value and immediately deductible).
    • Low Break-evens: Long-life, low decline assets afford Athabasca with a sustaining capital advantage. The Company’s 2025 Thermal Oil capital program which includes growth initiatives is fully funded within cash flow below US$50/bbl WTI. Long term sustaining capital investment is estimated at ~C$8/bbl (five‐year annual average) to hold production flat.

    2025 Corporate Guidance

    • Consolidated Production Outlook: The Company anticipates production at the upper end of guidance of 37,500 – 39,500 boe/d with an exit rate of ~41,000 boe/d. Thermal Oil production is trending at the upper end of its prior guidance of 33,500 – 35,500 bbl/d. Duvernay Energy is expected to average ~4,000 boe/d with an exit target of ~6,000 boe/d following the tie-in of two multi-well pads.
    • Thermal Capital: The forecast capital budget for Thermal oil is unchanged at ~$250 million, including sustaining capital and the Leismer expansion project. This $300 million expansion project (over three years) is highly economic (~$25,000/bbl/d capital efficiency) and provides flexibility with interim growth targets to ~32,000 bbl/d in H2 2026 and ~35,000 bbl/d in H1 2027 before achieving the regulatory approved 40,000 bbl/d capacity at the end of 2027. Athabasca’s Thermal Oil capital projects are flexible, highly economic and have phased optionality on timing based on the macroeconomic environment. By year-end 2025, the Company anticipates being ~50% complete of total capital exposure for the expansion project.
    • Duvernay Energy Corporation Capital: The 2025 capital program of ~$75 million will drive production momentum in H2 2025. The capital program in DEC is flexible and designed to be self-funded. The Company has a deep inventory of ~444 gross future drilling locations with no near-term land expiries.
    • Free Cash Flow Focus: The Company forecasts consolidated Adjusted Funds Flow between $525 – $550 million1, including $475 – $500 million from its Thermal Oil assets. 2025 Thermal Oil Free Cash Flow is forecasted at ~$250 million and is planned to be returned to shareholders through share buybacks. Every +US$1/bbl move in West Texas Intermediate (“WTI”) and Western Canadian Select (“WCS”) heavy oil impacts annual Adjusted Funds Flow by ~$10 million and ~$17 million, respectively.

    Corporate Consolidated Strategy

    • Value Creation: The Company’s Thermal Oil division provides a differentiated liquids weighted growth platform supported by financial resiliency to execute on return of capital initiatives. Athabasca’s subsidiary company, Duvernay Energy Corporation, is designed to enhance value for Athabasca’s shareholders by providing a clear path for self-funded production and cash flow growth in the Kaybob Duvernay resource play. Athabasca (Thermal Oil) and DEC have independent strategies and capital allocation frameworks.
    • Steadfast Focus on Cash Flow Per Share Growth: Athabasca’s disciplined capital allocation framework is designed to unlock shareholder value by prioritizing multi-year cash flow per share growth. The Company forecasts ~20% compounded annual cash flow per share growth between 2025-2029 driven by investing in attractive capital projects and prioritizing share buybacks with 100% of Free Cash Flow. The Company sees significant intrinsic value not reflected in the current share price and intends to remain active with its share buyback strategy.

    Athabasca (Thermal Oil) Strategy

    • Large Resource Base: Athabasca’s top-tier assets underpin a strong Free Cash Flow outlook with low sustaining capital requirements. The long life, low decline asset base includes ~1.2 billion barrels of Proved plus Probable reserves and ~1 billion barrels of Contingent Resource.
    • Strong Financial Position: Prudent balance sheet management is a core tenet of Athabasca’s strategy. The Company has a Net Cash position of $119 million, Liquidity of $437 million (including $304 million cash) and a long-dated maturity of 2029 on its term debt.
    • Leismer Progressive Growth: This $300 million expansion project (over three years) is highly economic (~$25,000/bbl/d capital efficiency) and provides flexibility with interim growth targets to ~32,000 bbl/d in H2 2026 and ~35,000 bbl/d in H1 2027 before achieving the regulatory approved 40,000 bbl/d capacity at the end of 2027. On completion of the expansion project, the Company can maintain Leismer at 40,000 bbl/d for approximately fifty years (Proved plus Probable Reserves).
    • Sustaining Hangingstone: The Hangingstone asset is very competitive and continues to deliver meaningful cash flow contributions to the Company. The objective is to sustain production and maintain competitive netbacks ($36.51/bbl H1 2025 Operating Netback).
    • Corner – Future Optionality: The Company’s Corner asset is a large de-risked oil sands asset adjacent to Leismer with 351 million barrels of Proved plus Probable reserves and 520 million barrels Contingent Resource (Best Estimate Unrisked). There are over 300 delineation wells and ~80% seismic coverage, with reservoir qualities similar to or better than Leismer. The asset has a 40,000 bbl/d regulatory approval for development with the existing pipeline corridor passing through the Corner lease. The Company has updated its development plans and is finalizing facility cost estimates, with a focus on capital efficient modular design.
    • Significant Multi-Year Free Cash Flow: Inclusive of the progressive growth at Leismer, Athabasca (Thermal Oil) expects to generate in excess of $1.8 billion of Free Cash Flow1 during the five-year time frame of 2025-29. Free Cash Flow will continue to support the Company’s return of capital initiatives.
    • Sound Heavy Oil Fundamentals: Canadian heavy oil markets remain strong supported by the Trans Mountain Expansion pipeline and sustained global refining demand. This has resulted in tighter and less volatile WCS heavy differentials with August index pricing at ~US$10/bbl. Athabasca is a direct beneficiary of structurally tighter differentials that are forecasted to hold in the coming years.
    • Thermal Oil Royalty Advantage: Athabasca has significant unrecovered capital balances on its Thermal Oil Assets that ensure a low Crown royalty framework (~6%1). Leismer is forecasted to remain pre-payout until late 20271 and Hangingstone is forecasted to remain pre-payout beyond 20301.
    • Tax Free Horizon Advantage: Athabasca (Thermal Oil) has $2.2 billion of valuable tax pools and does not forecast paying cash taxes this decade.

    Duvernay Energy Strategy

    • Accelerating Value: DEC is an operated, private subsidiary of Athabasca (owned 70% by Athabasca and 30% by Cenovus Energy). DEC accelerates value realization for Athabasca’s shareholders by providing a clear path for self-funded production and cash flow growth without compromising Athabasca’s capacity to fund its Thermal Oil assets or its return of capital strategy.
    • Kaybob Duvernay Focused: Exposure to ~200,000 gross acres in the liquids rich and oil windows with ~444 gross future well locations, including ~46,000 gross acres with 100% working interest.
    • Self-Funded Growth: Near-term activity will be funded within Adjusted Funds Flow, initial seed capital and the DEC credit facility. The Company has growth potential to in excess of ~20,000 boe/d (75% Liquids) by the late 2020s1.

    Footnote: Refer to the “Reader Advisory” section within this news release for additional information on Non‐GAAP Financial Measures (e.g. Adjusted Funds Flow, Free Cash Flow, Net Cash, Liquidity) and production disclosure.
    1 Pricing assumptions: H1 2025 actualized and US$65 WTI, US$12.50 WCS heavy differential, C$2 AECO, and 0.725 C$/US$ FX for H2 2025. 2026+ US$70 WTI, US$12.50 WCS heavy differential, C$3 AECO, and 0.725 C$/US$ FX

    Financial and Operational Highlights

      Three months ended
    June 30,
      Six months ended
    June 30,
     
    ($ Thousands, unless otherwise noted) 2025     2024     2025     2024    
    CORPORATE CONSOLIDATED(1)                
    Petroleum and natural gas production (boe/d)(2)   39,088       37,621       38,404       35,546    
    Petroleum, natural gas and midstream sales $ 360,070     $ 401,738     $ 727,914     $ 712,854    
    Operating Income(2) $ 141,707     $ 179,751     $ 287,297     $ 284,886    
    Operating Income Net of Realized Hedging(2)(3) $ 142,101     $ 178,176     $ 286,048     $ 284,756    
    Operating Netback ($/boe)(2) $ 38.81     $ 52.46     $ 41.30     $ 44.77    
    Operating Netback Net of Realized Hedging ($/boe)(2)(3) $ 38.92     $ 52.00     $ 41.12     $ 44.75    
    Capital expenditures $ 73,066     $ 48,453     $ 136,399     $ 124,464    
    Cash flow from operating activities $ 101,432     $ 135,083     $ 224,785     $ 211,721    
    per share – basic $ 0.20     $ 0.24     $ 0.44     $ 0.38    
    Adjusted Funds Flow(2) $ 127,591     $ 165,746     $ 257,266     $ 253,518    
    per share – basic $ 0.25     $ 0.30     $ 0.51     $ 0.45    
    ATHABASCA (THERMAL OIL)                
    Bitumen production (bbl/d)(2)   36,476       33,765       35,613       32,651    
    Petroleum, natural gas and midstream sales $ 355,160     $ 395,279     $ 717,535     $ 700,320    
    Operating Income(2) $ 135,803     $ 161,694     $ 271,119     $ 262,143    
    Operating Netback ($/bbl)(2) $ 39.79     $ 52.59     $ 42.02     $ 44.91    
    Capital expenditures $ 56,110     $ 34,084     $ 106,486     $ 76,203    
    Adjusted Funds Flow(2) $ 122,097     $ 149,413     $ 243,450     $ 233,126    
    Free Cash Flow(2) $ 65,987     $ 115,329     $ 136,964     $ 156,923    
    DUVERNAY ENERGY(1)                
    Petroleum and natural gas production (boe/d)(2)   2,612       3,856       2,791       2,895    
    Percentage Liquids (%)(2) 72 %   80 %   73 %   77 %  
    Petroleum, natural gas and midstream sales $ 13,526     $ 26,749     $ 31,145     $ 38,287    
    Operating Income(2) $ 5,904     $ 18,057     $ 16,178     $ 22,743    
    Operating Netback ($/boe)(2) $ 24.84     $ 51.46     $ 32.03     $ 43.17    
    Capital expenditures $ 16,956     $ 14,369     $ 29,913     $ 48,261    
    Adjusted Funds Flow(2) $ 5,494     $ 16,333     $ 13,816     $ 20,392    
    Free Cash Flow(2) $ (11,462 )   $ 1,964     $ (16,097 )   $ (27,869 )  
    NET INCOME AND COMPREHENSIVE INCOME                
    Net income and comprehensive income(4) $ 56,870     $ 96,076     $ 128,874     $ 134,685    
    per share – basic(4) $ 0.11     $ 0.17     $ 0.25     $ 0.24    
    per share – diluted(4) $ 0.11     $ 0.17     $ 0.25     $ 0.24    
    COMMON SHARES OUTSTANDING                
    Weighted average shares outstanding – basic   502,593,860       557,299,962       508,393,229       562,188,451    
    Weighted average shares outstanding – diluted   510,591,132       566,559,671       512,076,328       569,058,329    
      June 30,   December 31,  
    As at ($ Thousands) 2025   2024  
    LIQUIDITY AND BALANCE SHEET (CONSOLIDATED)        
    Cash and cash equivalents $ 304,048   $ 344,836  
    Available credit facilities(5) $ 133,074   $ 136,324  
    Face value of term debt $ 200,000   $ 200,000  
     
    (1) Corporate Consolidated and Duvernay Energy reflect gross production and financial metrics before taking into consideration Athabasca’s 70% equity interest in Duvernay Energy.
    (2) Refer to the “Reader Advisory” section within this News Release for additional information on Non-GAAP Financial Measures and production disclosure.
    (3) Includes realized commodity risk management gain of $0.4 million and loss of $1.2 million for the three and six months ended June 30, 2025 (three and six months ended June 30, 2024 – loss of $1.6 million and $0.1 million).
    (4) Net income and comprehensive income per share amounts are based on net income and comprehensive income attributable to shareholders of the Parent Company. In the calculation of diluted net income per share for the three months ended June 30, 2025 net income was increased by $0.4 million, to account for the impact to net income had the outstanding warrants been converted to equity. In the calculation of diluted net income per share for the three months ended June 30, 2024 net income was reduced by $0.4 million, to account for the impact to net income had the outstanding warrants been converted to equity.
    (5) Includes available credit under Athabasca’s and Duvernay Energy’s Credit Facilities and Athabasca’s Unsecured Letter of Credit Facility.
     

    Athabasca (Thermal Oil) Q2 2025 Highlights and Operations Update

    • Production: Production of 36,476 bbl/d (27,818 bbl/d at Leismer and 8,658 bbl/d at Hangingstone).
    • Cash Flow: Adjusted Funds Flow of $122.1 million; Operating Income of $135.8 million with an Operating Netback of $39.79/bbl ($42.02/bbl H1 2025).
    • Capital: $56.1 million of capital expenditures in Q2, with $53.9 million at Leismer as the Company advances the 40,000 bbl/d progressive growth project.
    • Free Cash Flow: $66.0 million of Free Cash Flow supporting return of capital commitment.

    Leismer

    Earlier this year, the Company brought six extended reach redrills on Pad L1 (1,000 – 1,700 meter laterals) on production supporting current production of ~28,000 bbl/d (June 2025). Four well pairs on Pad L10 are expected to maintain production rates at facility capacity for the balance of 2025. The first two wells started steaming in April with production expected in Q3, and the final two will begin steaming this summer with first production expected in Q4. Another six well pairs will be drilled on Pad 11 in H2 2025.

    Activity at Leismer remains focused on advancing progressive growth to 40,000 bbl/d by the end of 2027. The project cost is estimated at $300 million generating a capital efficiency of approximately $25,000/bbl/d. The $300 million will be spent between 2025 and 2027 and includes an estimated $190 million for facility capital and an estimated $110 million for growth wells. By year-end 2025, the Company anticipates being ~50% complete of total capital exposure for the expansion project. The project remains on budget and on schedule with the original sanction plans announced in July 2024. The progressive build provides flexibility with interim growth targets to ~32,000 bbl/d in H2 2026 following the next planned turnaround, and ~35,000 bbl/d in H1 2027 before achieving the regulatory approved 40,000 bbl/d capacity at the end of 2027.

    Hangingstone

    At Hangingstone, two extended reach sustaining well pairs (~1,400 meter average laterals) were placed on production in March with production of ~8,900 bbl/d (June 2025). The well pairs ramped up faster than anticipated, benefiting from favorable reservoir temperatures and pressure supported by offsetting wells. Current well pair performance between 800 – 1,000 bbl/d per well has exceeded management’s expectations. Hangingstone continues to deliver meaningful cash flow contributions to the Company.

    Duvernay Energy Corporation Q2 2025 Highlights and Operations Update

    • Production: Production of 2,612 boe/d (72% Liquids).
    • Cash Flow: Adjusted Funds Flow of $5.5 million with an Operating Netback of $24.84/boe ($32.03/boe H1 2025).
    • Capital: $17.0 million of capital expenditures including completions on a 30% working interest four-well pad.  

    During the quarter completions operations commenced on a four well pad (30% working interest) with average laterals of ~5,000 meters. Completion operations on this pad were completed in mid July and the wells are expected to be on production in early August. A three well pad (100% working interest) is scheduled to be completed in early Fall and on production shortly thereafter. Earlier in 2025, a strategic gathering system was completed connecting the operated wells to existing operated infrastructure.

    Production from new wells drilled in 2024 continue to validate DEC’s type curve expectations. The five wells placed on production have averaged IP30’s of ~1,200 boe/d per well (86% Liquids) and IP90s of ~940 boe/d (86% Liquids) per well.

    DEC retains significant operational flexibility with no near-term land expiries and the ability to adjust spending in response to commodity price movements.

    About Athabasca Oil Corporation

    Athabasca Oil Corporation is a Canadian energy company with a focused strategy on the development of thermal and light oil assets. Situated in Alberta’s Western Canadian Sedimentary Basin, the Company has amassed a significant land base of extensive, high quality resources. Athabasca’s light oil assets are held in a private subsidiary (Duvernay Energy Corporation) in which Athabasca owns a 70% equity interest. Athabasca’s common shares trade on the TSX under the symbol “ATH”. For more information, visit www.atha.com.

    For more information, please contact:

    Reader Advisory:

    This News Release contains forward-looking information that involves various risks, uncertainties and other factors. All information other than statements of historical fact is forward-looking information. The use of any of the words “anticipate”, “plan”, “project”, “continue”, “maintain”, “may”, “estimate”, “expect”, “will”, “target”, “forecast”, “could”, “intend”, “potential”, “guidance”, “outlook” and similar expressions suggesting future outcome are intended to identify forward-looking information. The forward-looking information is not historical fact, but rather is based on the Company’s current plans, objectives, goals, strategies, estimates, assumptions and projections about the Company’s industry, business and future operating and financial results. This information involves known and unknown risks, uncertainties and other factors that may cause actual results or events to differ materially from those anticipated in such forward-looking information. No assurance can be given that these expectations will prove to be correct and such forward-looking information included in this News Release should not be unduly relied upon. This information speaks only as of the date of this News Release. In particular, this News Release contains forward-looking information pertaining to, but not limited to, the following: our strategic plans; the allocation of future capital; timing and quantum for shareholder returns including share buybacks; the terms of our NCIB program; our drilling plans and capital efficiencies; production growth to expected production rates and estimated sustaining capital amounts; timing of Leismer’s and Hangingstone’s pre-payout royalty status; applicability of tax pools; Adjusted Funds Flow and Free Cash Flow over various periods; type well economic metrics; number of drilling locations; forecasted daily production and the composition of production; break-even metrics, our outlook in respect of the Company’s business environment, including in respect of commodity pricing; and other matters.

    In addition, information and statements in this News Release relating to “Reserves” and “Resources” are deemed to be forward-looking information, as they involve the implied assessment, based on certain estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated, and that the reserves and resources described can be profitably produced in the future. With respect to forward-looking information contained in this News Release, assumptions have been made regarding, among other things: commodity prices; the regulatory framework governing royalties, taxes and environmental matters in the jurisdictions in which the Company conducts and will conduct business and the effects that such regulatory framework will have on the Company, including on the Company’s financial condition and results of operations; the Company’s financial and operational flexibility; the Company’s financial sustainability; Athabasca’s cash flow break-even commodity price; the Company’s ability to obtain qualified staff and equipment in a timely and cost-efficient manner; the applicability of technologies for the recovery and production of the Company’s reserves and resources; future capital expenditures to be made by the Company; future sources of funding for the Company’s capital programs; the Company’s future debt levels; future production levels; the Company’s ability to obtain financing and/or enter into joint venture arrangements, on acceptable terms; operating costs; compliance of counterparties with the terms of contractual arrangements; impact of increasing competition globally; collection risk of outstanding accounts receivable from third parties; geological and engineering estimates in respect of the Company’s reserves and resources; recoverability of reserves and resources; the geography of the areas in which the Company is conducting exploration and development activities and the quality of its assets. Certain other assumptions related to the Company’s Reserves and Resources are contained in the report of McDaniel & Associates Consultants Ltd. (“McDaniel”) evaluating Athabasca’s Proved Reserves, Probable Reserves and Contingent Resources as at December 31, 2024 (which is respectively referred to herein as the “McDaniel Report”).

    Actual results could differ materially from those anticipated in this forward-looking information as a result of the risk factors set forth in the Company’s Annual Information Form (“AIF”) dated March 5, 2025 available on SEDAR at www.sedarplus.ca, including, but not limited to: weakness in the oil and gas industry; exploration, development and production risks; prices, markets and marketing; market conditions; trade relations and tariffs; climate change and carbon pricing risk; statutes and regulations regarding the environment including deceptive marketing provisions; regulatory environment and changes in applicable law; gathering and processing facilities, pipeline systems and rail; reputation and public perception of the oil and gas sector; environment, social and governance goals; political uncertainty; state of capital markets; ability to finance capital requirements; access to capital and insurance; abandonment and reclamation costs; changing demand for oil and natural gas products; anticipated benefits of acquisitions and dispositions; royalty regimes; foreign exchange rates and interest rates; reserves; hedging; operational dependence; operating costs; project risks; supply chain disruption; financial assurances; diluent supply; third party credit risk; indigenous claims; reliance on key personnel and operators; income tax; cybersecurity; advanced technologies; hydraulic fracturing; liability management; seasonality and weather conditions; unexpected events; internal controls; limitations and insurance; litigation; natural gas overlying bitumen resources; competition; chain of title and expiration of licenses and leases; breaches of confidentiality; new industry related activities or new geographical areas; water use restrictions and/or limited access to water; relationship with Duvernay Energy Corporation; management estimates and assumptions; third-party claims; conflicts of interest; inflation and cost management; credit ratings; growth management; impact of pandemics; ability of investors resident in the United States to enforce civil remedies in Canada; and risks related to our debt and securities. All subsequent forward-looking information, whether written or oral, attributable to the Company or persons acting on its behalf are expressly qualified in their entirety by these cautionary statements.

    Also included in this News Release are estimates of Athabasca’s 2025 outlook which are based on the various assumptions as to production levels, commodity prices, currency exchange rates and other assumptions disclosed in this News Release. To the extent any such estimate constitutes a financial outlook, it was approved by management and the Board of Directors of Athabasca and is included to provide readers with an understanding of the Company’s outlook. Management does not have firm commitments for all of the costs, expenditures, prices or other financial assumptions used to prepare the financial outlook or assurance that such operating results will be achieved and, accordingly, the complete financial effects of all of those costs, expenditures, prices and operating results are not objectively determinable. The actual results of operations of the Company and the resulting financial results may vary from the amounts set forth herein, and such variations may be material. The outlook and forward-looking information contained in this New Release was made as of the date of this News release and the Company disclaims any intention or obligations to update or revise such outlook and/or forward-looking information, whether as a result of new information, future events or otherwise, unless required pursuant to applicable law.

    Oil and Gas Information

    “BOEs” may be misleading, particularly if used in isolation. A BOE conversion ratio of six thousand cubic feet of natural gas to one barrel of oil equivalent (6 Mcf: 1 bbl) is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. As the value ratio between natural gas and crude oil based on the current prices of natural gas and crude oil is significantly different from the energy equivalency of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value.

    Initial Production Rates 

    Test Results and Initial Production Rates: The well test results and initial production rates provided herein should be considered to be preliminary, except as otherwise indicated. Test results and initial production rates disclosed herein may not necessarily be indicative of long-term performance or of ultimate recovery.

    Reserves Information

    The McDaniel Report was prepared using the assumptions and methodology guidelines outlined in the COGE Handbook and in accordance with National Instrument 51-101 Standards of Disclosure for Oil and Gas Activities, effective December 31, 2024. There are numerous uncertainties inherent in estimating quantities of bitumen, light crude oil and medium crude oil, tight oil, conventional natural gas, shale gas and natural gas liquids reserves and the future cash flows attributed to such reserves. The reserve and associated cash flow information set forth above are estimates only. In general, estimates of economically recoverable reserves and the future net cash flows therefrom are based upon a number of variable factors and assumptions, such as historical production from the properties, production rates, ultimate reserve recovery, timing and amount of capital expenditures, marketability of oil and natural gas, royalty rates, the assumed effects of regulation by governmental agencies and future operating costs, all of which may vary materially. For those reasons, estimates of the economically recoverable reserves attributable to any particular group of properties, classification of such reserves based on risk of recovery and estimates of future net revenues associated with reserves prepared by different engineers, or by the same engineers at different times, may vary. The Company’s actual production, revenues, taxes and development and operating expenditures with respect to its reserves will vary from estimates thereof and such variations could be material. Reserves figures described herein have been rounded to the nearest MMbbl or MMboe. For additional information regarding the consolidated reserves and information concerning the resources of the Company as evaluated by McDaniel in the McDaniel Report, please refer to the Company’s AIF.

    Reserve Values (i.e. Net Asset Value) is calculated using the estimated net present value of all future net revenue from our reserves, before income taxes discounted at 10%, as estimated by McDaniel effective December 31, 2024 and based on average pricing of McDaniel, Sproule and GLJ as of January 1, 2025.

    The 444 gross Duvernay drilling locations referenced include: 87 proved undeveloped locations and 85 probable undeveloped locations for a total of 172 booked locations with the balance being unbooked locations. Proved undeveloped locations and probable undeveloped locations are booked and derived from the Company’s most recent independent reserves evaluation as prepared by McDaniel as of December 31, 2024 and account for drilling locations that have associated proved and/or probable reserves, as applicable. Unbooked locations are internal management estimates. Unbooked locations do not have attributed reserves or resources (including contingent or prospective). Unbooked locations have been identified by management as an estimation of Athabasca’s multi-year drilling activities expected to occur over the next two decades based on evaluation of applicable geologic, seismic, engineering, production and reserves information. There is no certainty that the Company will drill all unbooked drilling locations and if drilled there is no certainty that such locations will result in additional oil and gas reserves, resources or production. The drilling locations on which the Company will actually drill wells, including the number and timing thereof is ultimately dependent upon the availability of funding, commodity prices, provincial fiscal and royalty policies, costs, actual drilling results, additional reservoir information that is obtained and other factors.

    Non-GAAP and Other Financial Measures, and Production Disclosure

    The “Corporate Consolidated Adjusted Funds Flow”, “Corporate Consolidated Adjusted Funds Flow per Share”, “Athabasca (Thermal Oil) Adjusted Funds Flow”, “Duvernay Energy Adjusted Funds Flow”, “Corporate Consolidated Free Cash Flow”, “Athabasca (Thermal Oil) Free Cash Flow”, “Duvernay Energy Free Cash Flow”, “Corporate Consolidated Operating Income”, “Corporate Consolidated Operating Income Net of Realized Hedging”, “Athabasca (Thermal Oil) Operating Income”, “Duvernay Energy Operating Income”, “Corporate Consolidated Operating Netback”, “Corporate Consolidated Operating Netback Net of Realized Hedging”, “Athabasca (Thermal Oil) Operating Netback”, “Duvernay Energy Operating Netback” and “Cash Transportation and Marketing Expense” financial measures contained in this News Release do not have standardized meanings which are prescribed by IFRS and they are considered to be non-GAAP financial measures or ratios. These measures may not be comparable to similar measures presented by other issuers and should not be considered in isolation with measures that are prepared in accordance with IFRS. Net Cash and Liquidity are supplementary financial measures. The Leismer and Hangingstone operating results are supplementary financial measures that when aggregated, combine to the Athabasca (Thermal Oil) segment results.

    Adjusted Funds Flow, Adjusted Funds Flow Per Share and Free Cash Flow

    Adjusted Funds Flow and Free Cash Flow are non-GAAP financial measures and are not intended to represent cash flow from operating activities, net earnings or other measures of financial performance calculated in accordance with IFRS. The Adjusted Funds Flow and Free Cash Flow measures allow management and others to evaluate the Company’s ability to fund its capital programs and meet its ongoing financial obligations using cash flow internally generated from ongoing operating related activities. Adjusted Funds Flow per share is a non-GAAP financial ratio calculated as Adjusted Funds Flow divided by the applicable number of weighted average shares outstanding. Adjusted Funds Flow and Free Cash Flow are calculated as follows:

      Three months ended
    June 30, 2025
     
     ($ Thousands) Athabasca
    (Thermal Oil)
      Duvernay Energy(1)   Corporate
    Consolidated(1)
     
    Cash flow from operating activities $ 101,142   $ 290   $ 101,432  
    Changes in non-cash working capital   20,922     5,207     26,129  
    Settlement of provisions   33     (3 )   30  
    ADJUSTED FUNDS FLOW   122,097     5,494     127,591  
    Capital expenditures   (56,110 )   (16,956 )   (73,066 )
    FREE CASH FLOW $ 65,987   $ (11,462 ) $ 54,525  
    (1) Duvernay Energy and Corporate Consolidated reflect gross financial metrics before taking into consideration Athabasca’s 70% equity interest in Duvernay Energy.
      Six months ended
    June 30, 2025
     
     ($ Thousands) Athabasca
    (Thermal Oil)
      Duvernay Energy(1)   Corporate
    Consolidated(1)
     
    Cash flow from operating activities $ 214,569   $ 10,216   $ 224,785  
    Changes in non-cash working capital   28,152     3,595     31,747  
    Settlement of provisions   729     5     734  
     ADJUSTED FUNDS FLOW   243,450     13,816     257,266  
    Capital expenditures   (106,486 )   (29,913 )   (136,399 )
     FREE CASH FLOW $ 136,964   $ (16,097 ) $ 120,867  
    (1) Duvernay Energy and Corporate Consolidated reflect gross financial metrics before taking into consideration Athabasca’s 70% equity interest in Duvernay Energy.
      Three months ended
    June 30, 2024
     
     ($ Thousands) Athabasca
    (Thermal Oil)
      Duvernay Energy(1)   Corporate
    Consolidated(1)
     
    Cash flow from operating activities $ 124,027   $ 11,056   $ 135,083  
    Changes in non-cash working capital   25,375     5,390     30,765  
    Settlement of provisions   11     (113 )   (102 )
    ADJUSTED FUNDS FLOW   149,413     16,333     165,746  
    Capital expenditures   (34,084 )   (14,369 )   (48,453 )
    FREE CASH FLOW $ 115,329   $ 1,964   $ 117,293  
    (1) Duvernay Energy and Corporate Consolidated reflect gross financial metrics before taking into consideration Athabasca’s 70% equity interest in Duvernay Energy.
      Six months ended
    June 30, 2024
     
     ($ Thousands) Athabasca
    (Thermal Oil)
      Duvernay Energy(1)   Corporate
    Consolidated(1)
     
    Cash flow from operating activities $ 197,068   $ 14,653   $ 211,721  
    Changes in non-cash working capital   34,761     5,535     40,296  
    Settlement of provisions   1,297     204     1,501  
     ADJUSTED FUNDS FLOW   233,126     20,392     253,518  
    Capital expenditures   (76,203 )   (48,261 )   (124,464 )
     FREE CASH FLOW $ 156,923   $ (27,869 ) $ 129,054  
    (1) Duvernay Energy and Corporate Consolidated reflect gross financial metrics before taking into consideration Athabasca’s 70% equity interest in Duvernay Energy.
     

    Duvernay Energy Operating Income and Operating Netback

    The non-GAAP measure Duvernay Energy Operating Income in this News Release is calculated by subtracting the Duvernay Energy royalties, operating expenses and transportation & marketing expenses from petroleum and natural gas sales which is the most directly comparable GAAP measure. The Duvernay Energy Operating Netback per boe is a non-GAAP financial ratio calculated by dividing the Duvernay Energy Operating Income by the Duvernay Energy production. The Duvernay Energy Operating Income and the Duvernay Energy Operating Netback measures allow management and others to evaluate the production results from the Company’s Duvernay Energy assets.

    The Duvernay Energy Operating Income is calculated using the Duvernay Energy Segments GAAP results, as follows:

      Three months ended
    June 30,
      Six months ended
    June 30,
     
    ($ Thousands, unless otherwise noted) 2025   2024   2025   2024  
    Petroleum and natural gas sales $ 13,526   $ 26,749   $ 31,145   $ 38,287  
    Royalties   (1,792 )   (3,498 )   (4,553 )   (5,812 )
    Operating expenses   (4,870 )   (4,063 )   (8,656 )   (7,703 )
    Transportation and marketing   (960 )   (1,131 )   (1,758 )   (2,029 )
    DUVERNAY ENERGY OPERATING INCOME $ 5,904   $ 18,057   $ 16,178   $ 22,743  
                             

    Athabasca (Thermal Oil) Operating Income and Operating Netback

    The non-GAAP measure Athabasca (Thermal Oil) Operating Income in this News Release is calculated by subtracting the Athabasca (Thermal Oil) segments cost of diluent blending, royalties, operating expenses and cash transportation & marketing expenses from heavy oil (blended bitumen) and midstream sales which is the most directly comparable GAAP measure. The Athabasca (Thermal Oil) Operating Netback per bbl is a non-GAAP financial ratio calculated by dividing the respective projects Operating Income by its respective bitumen sales volumes. The Athabasca (Thermal Oil) Operating Income and the Athabasca (Thermal Oil) Operating Netback measures allow management and others to evaluate the production results from the Athabasca (Thermal Oil) assets.

    The Athabasca (Thermal Oil) Operating Income is calculated using the Athabasca (Thermal Oil) Segments GAAP results, as follows:

      Three months ended
    June 30,
      Six months ended
    June 30,
     
    ($ Thousands, unless otherwise noted) 2025   2024   2025   2024  
    Heavy oil (blended bitumen) and midstream sales $ 355,160   $ 395,279   $ 717,535   $ 700,320  
    Cost of diluent   (147,065 )   (148,166 )   (299,197 )   (282,026 )
    Total bitumen and midstream sales   208,095     247,113     418,338     418,294  
    Royalties   (9,431 )   (28,823 )   (25,395 )   (40,360 )
    Operating expenses – non-energy   (26,810 )   (24,417 )   (51,697 )   (47,542 )
    Operating expenses – energy   (13,621 )   (11,635 )   (27,128 )   (28,193 )
    Transportation and marketing(1)   (22,430 )   (20,544 )   (42,999 )   (40,056 )
    ATHABASCA (THERMAL OIL) OPERATING INCOME $ 135,803   $ 161,694   $ 271,119   $ 262,143  
    (1) Transportation and marketing excludes non-cash costs of $0.6 million and $1.1 million for the three and six months ended June 30, 2025 (three and six months ended June 30, 2024 – $0.6 million and $1.1 million).
     

    Corporate Consolidated Operating Income and Corporate Consolidated Operating Income Net of Realized Hedging and Operating Netbacks

    The non-GAAP measures of Corporate Consolidated Operating Income including or excluding realized hedging in this News Release are calculated by adding or subtracting realized gains (losses) on commodity risk management contracts (as applicable), royalties, the cost of diluent blending, operating expenses and cash transportation & marketing expenses from petroleum, natural gas and midstream sales which is the most directly comparable GAAP measure. The Corporate Consolidated Operating Netbacks including or excluding realized hedging per boe are non-GAAP ratios calculated by dividing Corporate Consolidated Operating Income including or excluding hedging by the total sales volumes and are presented on a per boe basis. The Corporate Consolidated Operating Income and Corporate Consolidated Operating Netbacks including or excluding realized hedging measures allow management and others to evaluate the production results from the Company’s Duvernay Energy and Athabasca (Thermal Oil) assets combined together including the impact of realized commodity risk management gains or losses (as applicable).

      Three months ended
    June 30,
      Six months ended
    June 30,
     
    ($ Thousands, unless otherwise noted) 2025   2024   2025   2024  
    Petroleum, natural gas and midstream sales(1) $ 368,686   $ 422,028   $ 748,680   $ 738,607  
    Royalties   (11,223 )   (32,321 )   (29,948 )   (46,172 )
    Cost of diluent(1)   (147,065 )   (148,166 )   (299,197 )   (282,026 )
    Operating expenses   (45,301 )   (40,115 )   (87,481 )   (83,438 )
    Transportation and marketing(2)   (23,390 )   (21,675 )   (44,757 )   (42,085 )
    Operating Income   141,707     179,751     287,297     284,886  
    Realized gain (loss) on commodity risk mgmt. contracts   394     (1,575 )   (1,249 )   (130 )
    OPERATING INCOME NET OF REALIZED HEDGING $ 142,101   $ 178,176   $ 286,048   $ 284,756  
    (1) Non-GAAP measure includes intercompany NGLs (i.e. condensate) sold by the Duvernay Energy segment to the Athabasca (Thermal Oil) segment for use as diluent that is eliminated on consolidation.
    (2) Transportation and marketing excludes non-cash costs of $0.6 million and $1.1 million for the three and six months ended June 30, 2025 (three and six months ended June 30, 2024 – $0.6 million and $1.1 million).
     

    Cash Transportation and Marketing Expense

    The Cash Transportation and Marketing Expense financial measures contained in this News Release are calculated by subtracting the non-cash transportation and marketing expense as reported in the Consolidated Statement of Cash Flows from the transportation and marketing expense as reported in the Consolidated Statement of Income (Loss) and are considered to be non-GAAP financial measures.

    Net Cash

    Net Cash is defined as the face value of term debt, plus accounts payable and accrued liabilities, plus current portion of provisions and other liabilities plus income tax payable less current assets, excluding risk management contracts.

    Liquidity

    Liquidity is defined as cash and cash equivalents plus available credit capacity.

    Production volumes details

        Three months ended
    June 30,
      Six months ended
    June 30,
     
    Production   2025   2024   2025   2024  
    Duvernay Energy:                  
    Oil and condensate NGLs(1) bbl/d   1,608     2,806     1,723     2,006  
    Other NGLs bbl/d   282     266     304     223  
    Natural gas(2) mcf/d   4,329     4,706     4,585     3,998  
    Total Duvernay Energy boe/d   2,612     3,856     2,791     2,895  
    Total Thermal Oil bitumen bbl/d   36,476     33,765     35,613     32,651  
    Total Company production boe/d   39,088     37,621     38,404     35,546  
    (1) Comprised of 99% or greater of tight oil, with the remaining being light and medium crude oil.
    (2) Comprised of 99% or greater of shale gas, with the remaining being conventional natural gas.
     

    This News Release also makes reference to Athabasca’s forecasted average daily Thermal Oil production of 33,500 ‐ 35,500 bbl/d for 2025. Athabasca expects that 100% of that production will be comprised of bitumen. Duvernay Energy’s forecasted total average daily production of ~4,000 boe/d for 2025 is expected to be comprised of approximately 65% tight oil, 25% shale gas and 10% NGLs.

    Liquids is defined as bitumen, light crude oil, medium crude oil and natural gas liquids.

    Break Even is an operating metric that calculates the US$WTI oil price required to fund operating costs (Operating Break-even), sustaining capital (Sustaining Break-even), or growth capital (Total Capital) within Adjusted Funds Flow.

    The MIL Network

  • MIL-OSI: Athabasca Oil Announces 2025 Second Quarter Results Highlighted by Strong Operational Results, Continued Share Buybacks and a Pristine Financial Position

    Source: GlobeNewswire (MIL-OSI)

    CALGARY, Alberta, July 24, 2025 (GLOBE NEWSWIRE) — Athabasca Oil Corporation (TSX: ATH) (“Athabasca” or the “Company”) is pleased to report its second quarter results marked by strong operational performance, consistent financial results and execution on return of capital commitments. With low corporate break-evens, differentiated long-life assets and a pristine balance sheet, the Company is well positioned to advance its strategic priorities.

    Q2 2025 Consolidated Corporate Results

    • Production: Average production of 39,088 boe/d (98% Liquids), representing 4% (15% per share) growth year-over-year.
    • Cash Flow: Adjusted Funds Flow of $128 million ($0.25 per share). Cash Flow from Operating Activities of $101 million. Free Cash Flow of $66 million from Athabasca (Thermal Oil).
    • Capital Program: $73 million total capital expenditures including $54 million at Leismer to support the 40,000 bbl/d phased growth project.
    • Shareholder Returns: Purchased 24 million shares through its buy-back program year-to-date. The Company is committed to returning 100% of Free Cash Flow (Thermal Oil) to shareholders in 2025 and has completed ~$600 million in share buybacks since March 31, 2023, reducing its fully diluted share count by 21%.

    Operations Highlights

    • Leismer: Production currently ~28,000 bbl/d (June 2025) with four sustaining well pairs expected to be placed on production through the balance of the year. The progressive growth project remains on time and on budget. The Company expects production to stay flat until the next growth plateau of 32,000 bbl/d in H2 2026.
    • Hangingstone: Production currently ~8,900 bbl/d (June 2025) following the start-up of two extended reach well pairs which are outperforming management’s expectations. The asset continues to deliver meaningful free cash flow generation.
    • Duvernay Energy (“DEC”): A four well pad (30% working interest) with ~5,000 meter laterals was completed in mid July and will be placed on production in August. Completion operations are expected to commence on a three well pad (100% working interest) in September. DEC is positioned for strong operational momentum into year end with an exit target of ~6,000 boe/d.

    Resilient Producer

    • Pristine Financial Position: The Company has a Net Cash position of $119 million, Liquidity of $437 million (including $304 million cash) and a long-dated maturity of 2029 on its term debt. The Company also has $2.2 billion of tax pools (~80% high-value and immediately deductible).
    • Low Break-evens: Long-life, low decline assets afford Athabasca with a sustaining capital advantage. The Company’s 2025 Thermal Oil capital program which includes growth initiatives is fully funded within cash flow below US$50/bbl WTI. Long term sustaining capital investment is estimated at ~C$8/bbl (five‐year annual average) to hold production flat.

    2025 Corporate Guidance

    • Consolidated Production Outlook: The Company anticipates production at the upper end of guidance of 37,500 – 39,500 boe/d with an exit rate of ~41,000 boe/d. Thermal Oil production is trending at the upper end of its prior guidance of 33,500 – 35,500 bbl/d. Duvernay Energy is expected to average ~4,000 boe/d with an exit target of ~6,000 boe/d following the tie-in of two multi-well pads.
    • Thermal Capital: The forecast capital budget for Thermal oil is unchanged at ~$250 million, including sustaining capital and the Leismer expansion project. This $300 million expansion project (over three years) is highly economic (~$25,000/bbl/d capital efficiency) and provides flexibility with interim growth targets to ~32,000 bbl/d in H2 2026 and ~35,000 bbl/d in H1 2027 before achieving the regulatory approved 40,000 bbl/d capacity at the end of 2027. Athabasca’s Thermal Oil capital projects are flexible, highly economic and have phased optionality on timing based on the macroeconomic environment. By year-end 2025, the Company anticipates being ~50% complete of total capital exposure for the expansion project.
    • Duvernay Energy Corporation Capital: The 2025 capital program of ~$75 million will drive production momentum in H2 2025. The capital program in DEC is flexible and designed to be self-funded. The Company has a deep inventory of ~444 gross future drilling locations with no near-term land expiries.
    • Free Cash Flow Focus: The Company forecasts consolidated Adjusted Funds Flow between $525 – $550 million1, including $475 – $500 million from its Thermal Oil assets. 2025 Thermal Oil Free Cash Flow is forecasted at ~$250 million and is planned to be returned to shareholders through share buybacks. Every +US$1/bbl move in West Texas Intermediate (“WTI”) and Western Canadian Select (“WCS”) heavy oil impacts annual Adjusted Funds Flow by ~$10 million and ~$17 million, respectively.

    Corporate Consolidated Strategy

    • Value Creation: The Company’s Thermal Oil division provides a differentiated liquids weighted growth platform supported by financial resiliency to execute on return of capital initiatives. Athabasca’s subsidiary company, Duvernay Energy Corporation, is designed to enhance value for Athabasca’s shareholders by providing a clear path for self-funded production and cash flow growth in the Kaybob Duvernay resource play. Athabasca (Thermal Oil) and DEC have independent strategies and capital allocation frameworks.
    • Steadfast Focus on Cash Flow Per Share Growth: Athabasca’s disciplined capital allocation framework is designed to unlock shareholder value by prioritizing multi-year cash flow per share growth. The Company forecasts ~20% compounded annual cash flow per share growth between 2025-2029 driven by investing in attractive capital projects and prioritizing share buybacks with 100% of Free Cash Flow. The Company sees significant intrinsic value not reflected in the current share price and intends to remain active with its share buyback strategy.

    Athabasca (Thermal Oil) Strategy

    • Large Resource Base: Athabasca’s top-tier assets underpin a strong Free Cash Flow outlook with low sustaining capital requirements. The long life, low decline asset base includes ~1.2 billion barrels of Proved plus Probable reserves and ~1 billion barrels of Contingent Resource.
    • Strong Financial Position: Prudent balance sheet management is a core tenet of Athabasca’s strategy. The Company has a Net Cash position of $119 million, Liquidity of $437 million (including $304 million cash) and a long-dated maturity of 2029 on its term debt.
    • Leismer Progressive Growth: This $300 million expansion project (over three years) is highly economic (~$25,000/bbl/d capital efficiency) and provides flexibility with interim growth targets to ~32,000 bbl/d in H2 2026 and ~35,000 bbl/d in H1 2027 before achieving the regulatory approved 40,000 bbl/d capacity at the end of 2027. On completion of the expansion project, the Company can maintain Leismer at 40,000 bbl/d for approximately fifty years (Proved plus Probable Reserves).
    • Sustaining Hangingstone: The Hangingstone asset is very competitive and continues to deliver meaningful cash flow contributions to the Company. The objective is to sustain production and maintain competitive netbacks ($36.51/bbl H1 2025 Operating Netback).
    • Corner – Future Optionality: The Company’s Corner asset is a large de-risked oil sands asset adjacent to Leismer with 351 million barrels of Proved plus Probable reserves and 520 million barrels Contingent Resource (Best Estimate Unrisked). There are over 300 delineation wells and ~80% seismic coverage, with reservoir qualities similar to or better than Leismer. The asset has a 40,000 bbl/d regulatory approval for development with the existing pipeline corridor passing through the Corner lease. The Company has updated its development plans and is finalizing facility cost estimates, with a focus on capital efficient modular design.
    • Significant Multi-Year Free Cash Flow: Inclusive of the progressive growth at Leismer, Athabasca (Thermal Oil) expects to generate in excess of $1.8 billion of Free Cash Flow1 during the five-year time frame of 2025-29. Free Cash Flow will continue to support the Company’s return of capital initiatives.
    • Sound Heavy Oil Fundamentals: Canadian heavy oil markets remain strong supported by the Trans Mountain Expansion pipeline and sustained global refining demand. This has resulted in tighter and less volatile WCS heavy differentials with August index pricing at ~US$10/bbl. Athabasca is a direct beneficiary of structurally tighter differentials that are forecasted to hold in the coming years.
    • Thermal Oil Royalty Advantage: Athabasca has significant unrecovered capital balances on its Thermal Oil Assets that ensure a low Crown royalty framework (~6%1). Leismer is forecasted to remain pre-payout until late 20271 and Hangingstone is forecasted to remain pre-payout beyond 20301.
    • Tax Free Horizon Advantage: Athabasca (Thermal Oil) has $2.2 billion of valuable tax pools and does not forecast paying cash taxes this decade.

    Duvernay Energy Strategy

    • Accelerating Value: DEC is an operated, private subsidiary of Athabasca (owned 70% by Athabasca and 30% by Cenovus Energy). DEC accelerates value realization for Athabasca’s shareholders by providing a clear path for self-funded production and cash flow growth without compromising Athabasca’s capacity to fund its Thermal Oil assets or its return of capital strategy.
    • Kaybob Duvernay Focused: Exposure to ~200,000 gross acres in the liquids rich and oil windows with ~444 gross future well locations, including ~46,000 gross acres with 100% working interest.
    • Self-Funded Growth: Near-term activity will be funded within Adjusted Funds Flow, initial seed capital and the DEC credit facility. The Company has growth potential to in excess of ~20,000 boe/d (75% Liquids) by the late 2020s1.

    Footnote: Refer to the “Reader Advisory” section within this news release for additional information on Non‐GAAP Financial Measures (e.g. Adjusted Funds Flow, Free Cash Flow, Net Cash, Liquidity) and production disclosure.
    1 Pricing assumptions: H1 2025 actualized and US$65 WTI, US$12.50 WCS heavy differential, C$2 AECO, and 0.725 C$/US$ FX for H2 2025. 2026+ US$70 WTI, US$12.50 WCS heavy differential, C$3 AECO, and 0.725 C$/US$ FX

    Financial and Operational Highlights

      Three months ended
    June 30,
      Six months ended
    June 30,
     
    ($ Thousands, unless otherwise noted) 2025     2024     2025     2024    
    CORPORATE CONSOLIDATED(1)                
    Petroleum and natural gas production (boe/d)(2)   39,088       37,621       38,404       35,546    
    Petroleum, natural gas and midstream sales $ 360,070     $ 401,738     $ 727,914     $ 712,854    
    Operating Income(2) $ 141,707     $ 179,751     $ 287,297     $ 284,886    
    Operating Income Net of Realized Hedging(2)(3) $ 142,101     $ 178,176     $ 286,048     $ 284,756    
    Operating Netback ($/boe)(2) $ 38.81     $ 52.46     $ 41.30     $ 44.77    
    Operating Netback Net of Realized Hedging ($/boe)(2)(3) $ 38.92     $ 52.00     $ 41.12     $ 44.75    
    Capital expenditures $ 73,066     $ 48,453     $ 136,399     $ 124,464    
    Cash flow from operating activities $ 101,432     $ 135,083     $ 224,785     $ 211,721    
    per share – basic $ 0.20     $ 0.24     $ 0.44     $ 0.38    
    Adjusted Funds Flow(2) $ 127,591     $ 165,746     $ 257,266     $ 253,518    
    per share – basic $ 0.25     $ 0.30     $ 0.51     $ 0.45    
    ATHABASCA (THERMAL OIL)                
    Bitumen production (bbl/d)(2)   36,476       33,765       35,613       32,651    
    Petroleum, natural gas and midstream sales $ 355,160     $ 395,279     $ 717,535     $ 700,320    
    Operating Income(2) $ 135,803     $ 161,694     $ 271,119     $ 262,143    
    Operating Netback ($/bbl)(2) $ 39.79     $ 52.59     $ 42.02     $ 44.91    
    Capital expenditures $ 56,110     $ 34,084     $ 106,486     $ 76,203    
    Adjusted Funds Flow(2) $ 122,097     $ 149,413     $ 243,450     $ 233,126    
    Free Cash Flow(2) $ 65,987     $ 115,329     $ 136,964     $ 156,923    
    DUVERNAY ENERGY(1)                
    Petroleum and natural gas production (boe/d)(2)   2,612       3,856       2,791       2,895    
    Percentage Liquids (%)(2) 72 %   80 %   73 %   77 %  
    Petroleum, natural gas and midstream sales $ 13,526     $ 26,749     $ 31,145     $ 38,287    
    Operating Income(2) $ 5,904     $ 18,057     $ 16,178     $ 22,743    
    Operating Netback ($/boe)(2) $ 24.84     $ 51.46     $ 32.03     $ 43.17    
    Capital expenditures $ 16,956     $ 14,369     $ 29,913     $ 48,261    
    Adjusted Funds Flow(2) $ 5,494     $ 16,333     $ 13,816     $ 20,392    
    Free Cash Flow(2) $ (11,462 )   $ 1,964     $ (16,097 )   $ (27,869 )  
    NET INCOME AND COMPREHENSIVE INCOME                
    Net income and comprehensive income(4) $ 56,870     $ 96,076     $ 128,874     $ 134,685    
    per share – basic(4) $ 0.11     $ 0.17     $ 0.25     $ 0.24    
    per share – diluted(4) $ 0.11     $ 0.17     $ 0.25     $ 0.24    
    COMMON SHARES OUTSTANDING                
    Weighted average shares outstanding – basic   502,593,860       557,299,962       508,393,229       562,188,451    
    Weighted average shares outstanding – diluted   510,591,132       566,559,671       512,076,328       569,058,329    
      June 30,   December 31,  
    As at ($ Thousands) 2025   2024  
    LIQUIDITY AND BALANCE SHEET (CONSOLIDATED)        
    Cash and cash equivalents $ 304,048   $ 344,836  
    Available credit facilities(5) $ 133,074   $ 136,324  
    Face value of term debt $ 200,000   $ 200,000  
     
    (1) Corporate Consolidated and Duvernay Energy reflect gross production and financial metrics before taking into consideration Athabasca’s 70% equity interest in Duvernay Energy.
    (2) Refer to the “Reader Advisory” section within this News Release for additional information on Non-GAAP Financial Measures and production disclosure.
    (3) Includes realized commodity risk management gain of $0.4 million and loss of $1.2 million for the three and six months ended June 30, 2025 (three and six months ended June 30, 2024 – loss of $1.6 million and $0.1 million).
    (4) Net income and comprehensive income per share amounts are based on net income and comprehensive income attributable to shareholders of the Parent Company. In the calculation of diluted net income per share for the three months ended June 30, 2025 net income was increased by $0.4 million, to account for the impact to net income had the outstanding warrants been converted to equity. In the calculation of diluted net income per share for the three months ended June 30, 2024 net income was reduced by $0.4 million, to account for the impact to net income had the outstanding warrants been converted to equity.
    (5) Includes available credit under Athabasca’s and Duvernay Energy’s Credit Facilities and Athabasca’s Unsecured Letter of Credit Facility.
     

    Athabasca (Thermal Oil) Q2 2025 Highlights and Operations Update

    • Production: Production of 36,476 bbl/d (27,818 bbl/d at Leismer and 8,658 bbl/d at Hangingstone).
    • Cash Flow: Adjusted Funds Flow of $122.1 million; Operating Income of $135.8 million with an Operating Netback of $39.79/bbl ($42.02/bbl H1 2025).
    • Capital: $56.1 million of capital expenditures in Q2, with $53.9 million at Leismer as the Company advances the 40,000 bbl/d progressive growth project.
    • Free Cash Flow: $66.0 million of Free Cash Flow supporting return of capital commitment.

    Leismer

    Earlier this year, the Company brought six extended reach redrills on Pad L1 (1,000 – 1,700 meter laterals) on production supporting current production of ~28,000 bbl/d (June 2025). Four well pairs on Pad L10 are expected to maintain production rates at facility capacity for the balance of 2025. The first two wells started steaming in April with production expected in Q3, and the final two will begin steaming this summer with first production expected in Q4. Another six well pairs will be drilled on Pad 11 in H2 2025.

    Activity at Leismer remains focused on advancing progressive growth to 40,000 bbl/d by the end of 2027. The project cost is estimated at $300 million generating a capital efficiency of approximately $25,000/bbl/d. The $300 million will be spent between 2025 and 2027 and includes an estimated $190 million for facility capital and an estimated $110 million for growth wells. By year-end 2025, the Company anticipates being ~50% complete of total capital exposure for the expansion project. The project remains on budget and on schedule with the original sanction plans announced in July 2024. The progressive build provides flexibility with interim growth targets to ~32,000 bbl/d in H2 2026 following the next planned turnaround, and ~35,000 bbl/d in H1 2027 before achieving the regulatory approved 40,000 bbl/d capacity at the end of 2027.

    Hangingstone

    At Hangingstone, two extended reach sustaining well pairs (~1,400 meter average laterals) were placed on production in March with production of ~8,900 bbl/d (June 2025). The well pairs ramped up faster than anticipated, benefiting from favorable reservoir temperatures and pressure supported by offsetting wells. Current well pair performance between 800 – 1,000 bbl/d per well has exceeded management’s expectations. Hangingstone continues to deliver meaningful cash flow contributions to the Company.

    Duvernay Energy Corporation Q2 2025 Highlights and Operations Update

    • Production: Production of 2,612 boe/d (72% Liquids).
    • Cash Flow: Adjusted Funds Flow of $5.5 million with an Operating Netback of $24.84/boe ($32.03/boe H1 2025).
    • Capital: $17.0 million of capital expenditures including completions on a 30% working interest four-well pad.  

    During the quarter completions operations commenced on a four well pad (30% working interest) with average laterals of ~5,000 meters. Completion operations on this pad were completed in mid July and the wells are expected to be on production in early August. A three well pad (100% working interest) is scheduled to be completed in early Fall and on production shortly thereafter. Earlier in 2025, a strategic gathering system was completed connecting the operated wells to existing operated infrastructure.

    Production from new wells drilled in 2024 continue to validate DEC’s type curve expectations. The five wells placed on production have averaged IP30’s of ~1,200 boe/d per well (86% Liquids) and IP90s of ~940 boe/d (86% Liquids) per well.

    DEC retains significant operational flexibility with no near-term land expiries and the ability to adjust spending in response to commodity price movements.

    About Athabasca Oil Corporation

    Athabasca Oil Corporation is a Canadian energy company with a focused strategy on the development of thermal and light oil assets. Situated in Alberta’s Western Canadian Sedimentary Basin, the Company has amassed a significant land base of extensive, high quality resources. Athabasca’s light oil assets are held in a private subsidiary (Duvernay Energy Corporation) in which Athabasca owns a 70% equity interest. Athabasca’s common shares trade on the TSX under the symbol “ATH”. For more information, visit www.atha.com.

    For more information, please contact:

    Reader Advisory:

    This News Release contains forward-looking information that involves various risks, uncertainties and other factors. All information other than statements of historical fact is forward-looking information. The use of any of the words “anticipate”, “plan”, “project”, “continue”, “maintain”, “may”, “estimate”, “expect”, “will”, “target”, “forecast”, “could”, “intend”, “potential”, “guidance”, “outlook” and similar expressions suggesting future outcome are intended to identify forward-looking information. The forward-looking information is not historical fact, but rather is based on the Company’s current plans, objectives, goals, strategies, estimates, assumptions and projections about the Company’s industry, business and future operating and financial results. This information involves known and unknown risks, uncertainties and other factors that may cause actual results or events to differ materially from those anticipated in such forward-looking information. No assurance can be given that these expectations will prove to be correct and such forward-looking information included in this News Release should not be unduly relied upon. This information speaks only as of the date of this News Release. In particular, this News Release contains forward-looking information pertaining to, but not limited to, the following: our strategic plans; the allocation of future capital; timing and quantum for shareholder returns including share buybacks; the terms of our NCIB program; our drilling plans and capital efficiencies; production growth to expected production rates and estimated sustaining capital amounts; timing of Leismer’s and Hangingstone’s pre-payout royalty status; applicability of tax pools; Adjusted Funds Flow and Free Cash Flow over various periods; type well economic metrics; number of drilling locations; forecasted daily production and the composition of production; break-even metrics, our outlook in respect of the Company’s business environment, including in respect of commodity pricing; and other matters.

    In addition, information and statements in this News Release relating to “Reserves” and “Resources” are deemed to be forward-looking information, as they involve the implied assessment, based on certain estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated, and that the reserves and resources described can be profitably produced in the future. With respect to forward-looking information contained in this News Release, assumptions have been made regarding, among other things: commodity prices; the regulatory framework governing royalties, taxes and environmental matters in the jurisdictions in which the Company conducts and will conduct business and the effects that such regulatory framework will have on the Company, including on the Company’s financial condition and results of operations; the Company’s financial and operational flexibility; the Company’s financial sustainability; Athabasca’s cash flow break-even commodity price; the Company’s ability to obtain qualified staff and equipment in a timely and cost-efficient manner; the applicability of technologies for the recovery and production of the Company’s reserves and resources; future capital expenditures to be made by the Company; future sources of funding for the Company’s capital programs; the Company’s future debt levels; future production levels; the Company’s ability to obtain financing and/or enter into joint venture arrangements, on acceptable terms; operating costs; compliance of counterparties with the terms of contractual arrangements; impact of increasing competition globally; collection risk of outstanding accounts receivable from third parties; geological and engineering estimates in respect of the Company’s reserves and resources; recoverability of reserves and resources; the geography of the areas in which the Company is conducting exploration and development activities and the quality of its assets. Certain other assumptions related to the Company’s Reserves and Resources are contained in the report of McDaniel & Associates Consultants Ltd. (“McDaniel”) evaluating Athabasca’s Proved Reserves, Probable Reserves and Contingent Resources as at December 31, 2024 (which is respectively referred to herein as the “McDaniel Report”).

    Actual results could differ materially from those anticipated in this forward-looking information as a result of the risk factors set forth in the Company’s Annual Information Form (“AIF”) dated March 5, 2025 available on SEDAR at www.sedarplus.ca, including, but not limited to: weakness in the oil and gas industry; exploration, development and production risks; prices, markets and marketing; market conditions; trade relations and tariffs; climate change and carbon pricing risk; statutes and regulations regarding the environment including deceptive marketing provisions; regulatory environment and changes in applicable law; gathering and processing facilities, pipeline systems and rail; reputation and public perception of the oil and gas sector; environment, social and governance goals; political uncertainty; state of capital markets; ability to finance capital requirements; access to capital and insurance; abandonment and reclamation costs; changing demand for oil and natural gas products; anticipated benefits of acquisitions and dispositions; royalty regimes; foreign exchange rates and interest rates; reserves; hedging; operational dependence; operating costs; project risks; supply chain disruption; financial assurances; diluent supply; third party credit risk; indigenous claims; reliance on key personnel and operators; income tax; cybersecurity; advanced technologies; hydraulic fracturing; liability management; seasonality and weather conditions; unexpected events; internal controls; limitations and insurance; litigation; natural gas overlying bitumen resources; competition; chain of title and expiration of licenses and leases; breaches of confidentiality; new industry related activities or new geographical areas; water use restrictions and/or limited access to water; relationship with Duvernay Energy Corporation; management estimates and assumptions; third-party claims; conflicts of interest; inflation and cost management; credit ratings; growth management; impact of pandemics; ability of investors resident in the United States to enforce civil remedies in Canada; and risks related to our debt and securities. All subsequent forward-looking information, whether written or oral, attributable to the Company or persons acting on its behalf are expressly qualified in their entirety by these cautionary statements.

    Also included in this News Release are estimates of Athabasca’s 2025 outlook which are based on the various assumptions as to production levels, commodity prices, currency exchange rates and other assumptions disclosed in this News Release. To the extent any such estimate constitutes a financial outlook, it was approved by management and the Board of Directors of Athabasca and is included to provide readers with an understanding of the Company’s outlook. Management does not have firm commitments for all of the costs, expenditures, prices or other financial assumptions used to prepare the financial outlook or assurance that such operating results will be achieved and, accordingly, the complete financial effects of all of those costs, expenditures, prices and operating results are not objectively determinable. The actual results of operations of the Company and the resulting financial results may vary from the amounts set forth herein, and such variations may be material. The outlook and forward-looking information contained in this New Release was made as of the date of this News release and the Company disclaims any intention or obligations to update or revise such outlook and/or forward-looking information, whether as a result of new information, future events or otherwise, unless required pursuant to applicable law.

    Oil and Gas Information

    “BOEs” may be misleading, particularly if used in isolation. A BOE conversion ratio of six thousand cubic feet of natural gas to one barrel of oil equivalent (6 Mcf: 1 bbl) is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. As the value ratio between natural gas and crude oil based on the current prices of natural gas and crude oil is significantly different from the energy equivalency of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value.

    Initial Production Rates 

    Test Results and Initial Production Rates: The well test results and initial production rates provided herein should be considered to be preliminary, except as otherwise indicated. Test results and initial production rates disclosed herein may not necessarily be indicative of long-term performance or of ultimate recovery.

    Reserves Information

    The McDaniel Report was prepared using the assumptions and methodology guidelines outlined in the COGE Handbook and in accordance with National Instrument 51-101 Standards of Disclosure for Oil and Gas Activities, effective December 31, 2024. There are numerous uncertainties inherent in estimating quantities of bitumen, light crude oil and medium crude oil, tight oil, conventional natural gas, shale gas and natural gas liquids reserves and the future cash flows attributed to such reserves. The reserve and associated cash flow information set forth above are estimates only. In general, estimates of economically recoverable reserves and the future net cash flows therefrom are based upon a number of variable factors and assumptions, such as historical production from the properties, production rates, ultimate reserve recovery, timing and amount of capital expenditures, marketability of oil and natural gas, royalty rates, the assumed effects of regulation by governmental agencies and future operating costs, all of which may vary materially. For those reasons, estimates of the economically recoverable reserves attributable to any particular group of properties, classification of such reserves based on risk of recovery and estimates of future net revenues associated with reserves prepared by different engineers, or by the same engineers at different times, may vary. The Company’s actual production, revenues, taxes and development and operating expenditures with respect to its reserves will vary from estimates thereof and such variations could be material. Reserves figures described herein have been rounded to the nearest MMbbl or MMboe. For additional information regarding the consolidated reserves and information concerning the resources of the Company as evaluated by McDaniel in the McDaniel Report, please refer to the Company’s AIF.

    Reserve Values (i.e. Net Asset Value) is calculated using the estimated net present value of all future net revenue from our reserves, before income taxes discounted at 10%, as estimated by McDaniel effective December 31, 2024 and based on average pricing of McDaniel, Sproule and GLJ as of January 1, 2025.

    The 444 gross Duvernay drilling locations referenced include: 87 proved undeveloped locations and 85 probable undeveloped locations for a total of 172 booked locations with the balance being unbooked locations. Proved undeveloped locations and probable undeveloped locations are booked and derived from the Company’s most recent independent reserves evaluation as prepared by McDaniel as of December 31, 2024 and account for drilling locations that have associated proved and/or probable reserves, as applicable. Unbooked locations are internal management estimates. Unbooked locations do not have attributed reserves or resources (including contingent or prospective). Unbooked locations have been identified by management as an estimation of Athabasca’s multi-year drilling activities expected to occur over the next two decades based on evaluation of applicable geologic, seismic, engineering, production and reserves information. There is no certainty that the Company will drill all unbooked drilling locations and if drilled there is no certainty that such locations will result in additional oil and gas reserves, resources or production. The drilling locations on which the Company will actually drill wells, including the number and timing thereof is ultimately dependent upon the availability of funding, commodity prices, provincial fiscal and royalty policies, costs, actual drilling results, additional reservoir information that is obtained and other factors.

    Non-GAAP and Other Financial Measures, and Production Disclosure

    The “Corporate Consolidated Adjusted Funds Flow”, “Corporate Consolidated Adjusted Funds Flow per Share”, “Athabasca (Thermal Oil) Adjusted Funds Flow”, “Duvernay Energy Adjusted Funds Flow”, “Corporate Consolidated Free Cash Flow”, “Athabasca (Thermal Oil) Free Cash Flow”, “Duvernay Energy Free Cash Flow”, “Corporate Consolidated Operating Income”, “Corporate Consolidated Operating Income Net of Realized Hedging”, “Athabasca (Thermal Oil) Operating Income”, “Duvernay Energy Operating Income”, “Corporate Consolidated Operating Netback”, “Corporate Consolidated Operating Netback Net of Realized Hedging”, “Athabasca (Thermal Oil) Operating Netback”, “Duvernay Energy Operating Netback” and “Cash Transportation and Marketing Expense” financial measures contained in this News Release do not have standardized meanings which are prescribed by IFRS and they are considered to be non-GAAP financial measures or ratios. These measures may not be comparable to similar measures presented by other issuers and should not be considered in isolation with measures that are prepared in accordance with IFRS. Net Cash and Liquidity are supplementary financial measures. The Leismer and Hangingstone operating results are supplementary financial measures that when aggregated, combine to the Athabasca (Thermal Oil) segment results.

    Adjusted Funds Flow, Adjusted Funds Flow Per Share and Free Cash Flow

    Adjusted Funds Flow and Free Cash Flow are non-GAAP financial measures and are not intended to represent cash flow from operating activities, net earnings or other measures of financial performance calculated in accordance with IFRS. The Adjusted Funds Flow and Free Cash Flow measures allow management and others to evaluate the Company’s ability to fund its capital programs and meet its ongoing financial obligations using cash flow internally generated from ongoing operating related activities. Adjusted Funds Flow per share is a non-GAAP financial ratio calculated as Adjusted Funds Flow divided by the applicable number of weighted average shares outstanding. Adjusted Funds Flow and Free Cash Flow are calculated as follows:

      Three months ended
    June 30, 2025
     
     ($ Thousands) Athabasca
    (Thermal Oil)
      Duvernay Energy(1)   Corporate
    Consolidated(1)
     
    Cash flow from operating activities $ 101,142   $ 290   $ 101,432  
    Changes in non-cash working capital   20,922     5,207     26,129  
    Settlement of provisions   33     (3 )   30  
    ADJUSTED FUNDS FLOW   122,097     5,494     127,591  
    Capital expenditures   (56,110 )   (16,956 )   (73,066 )
    FREE CASH FLOW $ 65,987   $ (11,462 ) $ 54,525  
    (1) Duvernay Energy and Corporate Consolidated reflect gross financial metrics before taking into consideration Athabasca’s 70% equity interest in Duvernay Energy.
      Six months ended
    June 30, 2025
     
     ($ Thousands) Athabasca
    (Thermal Oil)
      Duvernay Energy(1)   Corporate
    Consolidated(1)
     
    Cash flow from operating activities $ 214,569   $ 10,216   $ 224,785  
    Changes in non-cash working capital   28,152     3,595     31,747  
    Settlement of provisions   729     5     734  
     ADJUSTED FUNDS FLOW   243,450     13,816     257,266  
    Capital expenditures   (106,486 )   (29,913 )   (136,399 )
     FREE CASH FLOW $ 136,964   $ (16,097 ) $ 120,867  
    (1) Duvernay Energy and Corporate Consolidated reflect gross financial metrics before taking into consideration Athabasca’s 70% equity interest in Duvernay Energy.
      Three months ended
    June 30, 2024
     
     ($ Thousands) Athabasca
    (Thermal Oil)
      Duvernay Energy(1)   Corporate
    Consolidated(1)
     
    Cash flow from operating activities $ 124,027   $ 11,056   $ 135,083  
    Changes in non-cash working capital   25,375     5,390     30,765  
    Settlement of provisions   11     (113 )   (102 )
    ADJUSTED FUNDS FLOW   149,413     16,333     165,746  
    Capital expenditures   (34,084 )   (14,369 )   (48,453 )
    FREE CASH FLOW $ 115,329   $ 1,964   $ 117,293  
    (1) Duvernay Energy and Corporate Consolidated reflect gross financial metrics before taking into consideration Athabasca’s 70% equity interest in Duvernay Energy.
      Six months ended
    June 30, 2024
     
     ($ Thousands) Athabasca
    (Thermal Oil)
      Duvernay Energy(1)   Corporate
    Consolidated(1)
     
    Cash flow from operating activities $ 197,068   $ 14,653   $ 211,721  
    Changes in non-cash working capital   34,761     5,535     40,296  
    Settlement of provisions   1,297     204     1,501  
     ADJUSTED FUNDS FLOW   233,126     20,392     253,518  
    Capital expenditures   (76,203 )   (48,261 )   (124,464 )
     FREE CASH FLOW $ 156,923   $ (27,869 ) $ 129,054  
    (1) Duvernay Energy and Corporate Consolidated reflect gross financial metrics before taking into consideration Athabasca’s 70% equity interest in Duvernay Energy.
     

    Duvernay Energy Operating Income and Operating Netback

    The non-GAAP measure Duvernay Energy Operating Income in this News Release is calculated by subtracting the Duvernay Energy royalties, operating expenses and transportation & marketing expenses from petroleum and natural gas sales which is the most directly comparable GAAP measure. The Duvernay Energy Operating Netback per boe is a non-GAAP financial ratio calculated by dividing the Duvernay Energy Operating Income by the Duvernay Energy production. The Duvernay Energy Operating Income and the Duvernay Energy Operating Netback measures allow management and others to evaluate the production results from the Company’s Duvernay Energy assets.

    The Duvernay Energy Operating Income is calculated using the Duvernay Energy Segments GAAP results, as follows:

      Three months ended
    June 30,
      Six months ended
    June 30,
     
    ($ Thousands, unless otherwise noted) 2025   2024   2025   2024  
    Petroleum and natural gas sales $ 13,526   $ 26,749   $ 31,145   $ 38,287  
    Royalties   (1,792 )   (3,498 )   (4,553 )   (5,812 )
    Operating expenses   (4,870 )   (4,063 )   (8,656 )   (7,703 )
    Transportation and marketing   (960 )   (1,131 )   (1,758 )   (2,029 )
    DUVERNAY ENERGY OPERATING INCOME $ 5,904   $ 18,057   $ 16,178   $ 22,743  
                             

    Athabasca (Thermal Oil) Operating Income and Operating Netback

    The non-GAAP measure Athabasca (Thermal Oil) Operating Income in this News Release is calculated by subtracting the Athabasca (Thermal Oil) segments cost of diluent blending, royalties, operating expenses and cash transportation & marketing expenses from heavy oil (blended bitumen) and midstream sales which is the most directly comparable GAAP measure. The Athabasca (Thermal Oil) Operating Netback per bbl is a non-GAAP financial ratio calculated by dividing the respective projects Operating Income by its respective bitumen sales volumes. The Athabasca (Thermal Oil) Operating Income and the Athabasca (Thermal Oil) Operating Netback measures allow management and others to evaluate the production results from the Athabasca (Thermal Oil) assets.

    The Athabasca (Thermal Oil) Operating Income is calculated using the Athabasca (Thermal Oil) Segments GAAP results, as follows:

      Three months ended
    June 30,
      Six months ended
    June 30,
     
    ($ Thousands, unless otherwise noted) 2025   2024   2025   2024  
    Heavy oil (blended bitumen) and midstream sales $ 355,160   $ 395,279   $ 717,535   $ 700,320  
    Cost of diluent   (147,065 )   (148,166 )   (299,197 )   (282,026 )
    Total bitumen and midstream sales   208,095     247,113     418,338     418,294  
    Royalties   (9,431 )   (28,823 )   (25,395 )   (40,360 )
    Operating expenses – non-energy   (26,810 )   (24,417 )   (51,697 )   (47,542 )
    Operating expenses – energy   (13,621 )   (11,635 )   (27,128 )   (28,193 )
    Transportation and marketing(1)   (22,430 )   (20,544 )   (42,999 )   (40,056 )
    ATHABASCA (THERMAL OIL) OPERATING INCOME $ 135,803   $ 161,694   $ 271,119   $ 262,143  
    (1) Transportation and marketing excludes non-cash costs of $0.6 million and $1.1 million for the three and six months ended June 30, 2025 (three and six months ended June 30, 2024 – $0.6 million and $1.1 million).
     

    Corporate Consolidated Operating Income and Corporate Consolidated Operating Income Net of Realized Hedging and Operating Netbacks

    The non-GAAP measures of Corporate Consolidated Operating Income including or excluding realized hedging in this News Release are calculated by adding or subtracting realized gains (losses) on commodity risk management contracts (as applicable), royalties, the cost of diluent blending, operating expenses and cash transportation & marketing expenses from petroleum, natural gas and midstream sales which is the most directly comparable GAAP measure. The Corporate Consolidated Operating Netbacks including or excluding realized hedging per boe are non-GAAP ratios calculated by dividing Corporate Consolidated Operating Income including or excluding hedging by the total sales volumes and are presented on a per boe basis. The Corporate Consolidated Operating Income and Corporate Consolidated Operating Netbacks including or excluding realized hedging measures allow management and others to evaluate the production results from the Company’s Duvernay Energy and Athabasca (Thermal Oil) assets combined together including the impact of realized commodity risk management gains or losses (as applicable).

      Three months ended
    June 30,
      Six months ended
    June 30,
     
    ($ Thousands, unless otherwise noted) 2025   2024   2025   2024  
    Petroleum, natural gas and midstream sales(1) $ 368,686   $ 422,028   $ 748,680   $ 738,607  
    Royalties   (11,223 )   (32,321 )   (29,948 )   (46,172 )
    Cost of diluent(1)   (147,065 )   (148,166 )   (299,197 )   (282,026 )
    Operating expenses   (45,301 )   (40,115 )   (87,481 )   (83,438 )
    Transportation and marketing(2)   (23,390 )   (21,675 )   (44,757 )   (42,085 )
    Operating Income   141,707     179,751     287,297     284,886  
    Realized gain (loss) on commodity risk mgmt. contracts   394     (1,575 )   (1,249 )   (130 )
    OPERATING INCOME NET OF REALIZED HEDGING $ 142,101   $ 178,176   $ 286,048   $ 284,756  
    (1) Non-GAAP measure includes intercompany NGLs (i.e. condensate) sold by the Duvernay Energy segment to the Athabasca (Thermal Oil) segment for use as diluent that is eliminated on consolidation.
    (2) Transportation and marketing excludes non-cash costs of $0.6 million and $1.1 million for the three and six months ended June 30, 2025 (three and six months ended June 30, 2024 – $0.6 million and $1.1 million).
     

    Cash Transportation and Marketing Expense

    The Cash Transportation and Marketing Expense financial measures contained in this News Release are calculated by subtracting the non-cash transportation and marketing expense as reported in the Consolidated Statement of Cash Flows from the transportation and marketing expense as reported in the Consolidated Statement of Income (Loss) and are considered to be non-GAAP financial measures.

    Net Cash

    Net Cash is defined as the face value of term debt, plus accounts payable and accrued liabilities, plus current portion of provisions and other liabilities plus income tax payable less current assets, excluding risk management contracts.

    Liquidity

    Liquidity is defined as cash and cash equivalents plus available credit capacity.

    Production volumes details

        Three months ended
    June 30,
      Six months ended
    June 30,
     
    Production   2025   2024   2025   2024  
    Duvernay Energy:                  
    Oil and condensate NGLs(1) bbl/d   1,608     2,806     1,723     2,006  
    Other NGLs bbl/d   282     266     304     223  
    Natural gas(2) mcf/d   4,329     4,706     4,585     3,998  
    Total Duvernay Energy boe/d   2,612     3,856     2,791     2,895  
    Total Thermal Oil bitumen bbl/d   36,476     33,765     35,613     32,651  
    Total Company production boe/d   39,088     37,621     38,404     35,546  
    (1) Comprised of 99% or greater of tight oil, with the remaining being light and medium crude oil.
    (2) Comprised of 99% or greater of shale gas, with the remaining being conventional natural gas.
     

    This News Release also makes reference to Athabasca’s forecasted average daily Thermal Oil production of 33,500 ‐ 35,500 bbl/d for 2025. Athabasca expects that 100% of that production will be comprised of bitumen. Duvernay Energy’s forecasted total average daily production of ~4,000 boe/d for 2025 is expected to be comprised of approximately 65% tight oil, 25% shale gas and 10% NGLs.

    Liquids is defined as bitumen, light crude oil, medium crude oil and natural gas liquids.

    Break Even is an operating metric that calculates the US$WTI oil price required to fund operating costs (Operating Break-even), sustaining capital (Sustaining Break-even), or growth capital (Total Capital) within Adjusted Funds Flow.

    The MIL Network

  • MIL-OSI Banking: Newfoundland and Labrador issue RFEI for 150 MW capacity and 500 GWh energy

    Source: – Press Release/Statement:

    Headline: Newfoundland and Labrador issue RFEI for 150 MW capacity and 500 GWh energy

    CanREA members are eager to propose new, affordable, wind and solar energy projects in Newfoundland & Labrador.

    Toronto, July 24, 2025—The Canadian Renewable Energy Association (CanREA) welcomes Newfoundland and Labrador Hydro’s new Request for Expressions of Interest (RFEI), as announced July 9.

    An information session held by Newfoundland and Labrador Hydro on July 23 confirmed that this RFEI is for the supply of energy and/or capacity that, in combination, can provide up to 150 megawatts (MW) of firm capacity and up to 500 gigawatt hours (GWh) of firm energy, to meet the increasing demands of the province’s Island Interconnected System.

    “With this announcement, CanREA is now tracking wind energy, solar energy and energy storage activity coast-to-coast in Canada, with a clear focus on building clean energy projects at scale and pace,” said Vittoria Bellissimo, CanREA’s President and CEO.

    The RFEI will help the utility gather market information to support the development of a Request for Proposals (RFP) and a Request for Information (RFI) later this year.

    “Newfoundland and Labrador needs more power, and our members are ready to compete for the opportunity to develop wind, solar and battery storage projects to help meet these needs, provide affordable, reliable and clean electricity to Newfoundlanders and support economic growth across the province,” said Jean Habel, CanREA’s Senior Director for Québec and Atlantic Canada.  

    Wind and solar energy, coupled with energy storage capacity, can contribute to a decarbonized energy grid, create local economic benefits and improve the resilience of the electricity system.

    CanREA will continue to engage with Newfoundland and Labrador Hydro and the government of Newfoundland and Labrador to ensure this RFEI process will result in the lowest-cost, highest-benefit outcomes for consumers.  

    “This RFEI is a high-priority item for CanREA’s members in Atlantic Canada, and we are confident that it will build momentum in Newfoundland and Labrador over the coming years,” said Eddie Oldfield, CanREA’s Manager for Atlantic Canada. 

    The deadline for questions is Friday, August 1, 2025, at 11:59 p.m. (NDT, and the RFEI bid closing date is Tuesday, September 2, 2025, at 3 p.m. (NDT).

    Quotes

    “With this announcement, CanREA is now tracking wind energy, solar energy and energy storage activity coast-to-coast in Canada, with a clear focus on building clean energy projects at scale and pace.”
    —Vittoria Bellissimo, President and CEO, Canadian Renewable Energy Association (CanREA)

    “Newfoundland and Labrador needs more power, and our members are ready to compete for the opportunity to develop wind, solar and battery storage projects to help meet these needs, provide affordable, reliable and clean electricity to Newfoundlanders and support economic growth across the province.”
    —Jean Habel, Senior Director for Québec and Atlantic Canada, Canadian Renewable Energy Association (CanREA) 

    “This RFEI is a high-priority item for CanREA’s members in Atlantic Canada, and we are confident that it will build momentum in Newfoundland and Labrador over the coming years.”
    —Eddie Oldfield, Atlantic Canada Manager, Canadian Renewable Energy Association (CanREA)

    Canadian Renewable Energy Association 

    Communications Canadian Renewable Energy Association communications@renewablesassociation.ca 

    About CanREA 

    The Canadian Renewable Energy Association (CanREA) is the voice for wind energy, solar energy and energy storage solutions that will power Canada’s energy future. We work to create the conditions for a modern energy system through stakeholder advocacy and public engagement. Our diverse members are uniquely positioned to deliver clean, low-cost, reliable, flexible and scalable solutions for Canada’s energy needs. For more information on how Canada can use wind energy, solar energy and energy storage to help achieve its net-zero commitments, consult “Powering Canada’s Journey to Net-Zero: CanREA’s 2050 Vision.” Follow us on Bluesky and LinkedIn here. Learn more at renewablesassociation.ca. 

    The post Newfoundland and Labrador issue RFEI for 150 MW capacity and 500 GWh energy appeared first on Canadian Renewable Energy Association.

    MIL OSI Global Banks

  • MIL-OSI USA: Volcano Watch — Ancient volcanoes are critical to our modern world, and our future

    Source: US Geological Survey

    Volcano Watch is a weekly article and activity update written by U.S. Geological Survey Hawaiian Volcano Observatory scientists and affiliates. 

    The Ha‘akulamanu trail within Hawai‘i Volcanoes National Park passes through the Sulphur Banks area, where long-term degassing near Kaluapele (Kīlauea summit caldera) has altered the basalt to colorful minerals including yellow sulfur, white gypsum, and reddish-brown hematite. USGS photo by C. Sealing.

    Volcanoes act as windows into the deep Earth. They help us understand the formation of our planet and others like it in the solar system. Living on or near an active volcano can be both beneficial, due to their rich soils and tourism appeal, but they also pose hazards to the communities around them. For this reason, we need to understand what drives volcanic eruptions and monitor volcanoes to keep communities safe. 

    Long after magma has stopped rising through the crust and the last eruption at a volcano has ceased, another process takes places in volcanic systems deep underground. Fluids begin to percolate through the system—they flow through the old magma reservoirs, the dykes and sills, buried lava flows and hydrothermal systems—transporting elements and chemically altering the surrounding rocks. Unlike the geologically short and violent lives of volcanoes, the formation of mineral systems is a slow, quiet process that can take millions of years. 

    According to the Energy Act of 2020, “critical minerals” are those minerals, elements, substances, or materials designated as critical because they serve an essential function for energy technology and have a high risk of supply chain disruption. The list of critical minerals includes elements like lithium, nickel, magnesium, platinum, iridium, and rare earth elements, among others. These elements have become important for our everyday lives, and are used in everything from solar panels, batteries, vehicles, power plants, medical devices, to smartphones.

    More than half of the world’s critical mineral resources formed in ancient volcanic systems. When exploring for mineral resources, your location within the volcanic system will determine the type of ore bodies you’d expect to find. 

    For instance, deep in the volcanic system, minerals like chromium, titanium, vanadium, and platinum-group elements are found in layered intrusive rocks that were once bodies of magma that never made it to the surface.

    The most abundant source of rare earth elements are strange magmas called carbonatites that are found at the edges of ancient continents and in ancient rift systems within continents. In other volcanic systems, like submarine volcanoes, magmatic-hydrothermal systems yield minerals like copper, lead, zinc, and gold.

    The richest mineral deposits are often found in the oldest volcanic rocks. They’ve been weathered down, eroded, and buried, while fluids have moved through continuously altering the rocks themselves. You probably wouldn’t recognize them as old volcanic systems without a geology degree—and even then, it’s hard!

    As geologists, we use observations of our modern world to help us understand the formations of the past. Studying recent and active volcanic systems—where they form, how they’re shaped inside, what magmas they produce, and how they interact with the surrounding environment—allows us to better understand and explore for these ancient, mineral-bearing systems that power the modern and future world.  So, next time you visit a national park with volcanoes like Kīlauea or Yellowstone, imagine you are hiking on what could be a future ore deposit millions of years from now.

    Volcano Activity Updates

    Kīlauea has been erupting episodically within the summit caldera since December 23, 2024. Its USGS Volcano Alert level is WATCH.

    Episode 29 of the Kīlauea summit eruption in Halemaʻumaʻu crater occurred on July 20, with approximately 13 hours of fountaining from predominantly the north vent. Summit region inflation since the end of episode 29, along with persistent tremor, suggests that another episode is possible and could start July 31 or later. Sulfur dioxide emission rates are elevated in the summit region during active eruption episodes. No unusual activity has been noted along Kīlauea’s East Rift Zone or Southwest Rift Zone. 

    Mauna Loa is not erupting. Its USGS Volcano Alert Level is at NORMAL.

    One earthquake was reported felt in the Hawaiian Islands during the past week: a M3.1 earthquake 1 km (0 mi) S of Kealakekua at 9 km (5 mi) depth on July 21 at 9:07 p.m. HST.

    HVO continues to closely monitor Kīlauea and Mauna Loa.

    Please visit HVO’s website for past Volcano Watch articles, Kīlauea and Mauna Loa updates, volcano photos, maps, recent earthquake information, and more. Email questions to askHVO@usgs.gov.

    MIL OSI USA News

  • MIL-OSI Economics: Press Briefing Transcript: Julie Kozack, Director, Communications Department, July 24, 2025

    Source: International Monetary Fund

    July 24, 2025

    SPEAKER:  Ms. Julie Kozack, Director of the Communications Department, IMF

    MS. KOZACK: Good morning, and welcome to the IMF Press Briefing. It is wonderful to see all of you, both those of you here in person and colleagues online as well. I’m Julie Kozack, Director of the Communications Department at the IMF. As usual, this briefing is embargoed until 11 A.M. Eastern Time in the United States. I’ll start with a few announcements and then I’ll take your questions in person on Webex and via the Press Center.
    First, we will be releasing our flagship publication, the World Economic Outlook Update, next Tuesday, July 29th. The report will offer fresh insights into the current global economic trends and external imbalances.
    For your planning purposes, our Executive Board will be in recess from August 4th through the 15th, and we will notify you in due course on the date of our next press briefing.
    And with that, I will now open the floor for your questions. For those connecting virtually, please turn on both your camera and microphone when speaking, and the floor is opened.

    QUESTIONER: Just wanted to ask you about the tariff situation that’s unfolding at the moment, given the recent trade deals that the U.S. has struck with its key trading partners, including Japan, Indonesia, Philippines, just recently. The European Union is under negotiations that’s coming to fruition soon. It looks like the consensus is kind of around a 15 to 20% tariff rate in that range, that the US is, sort of agreeing with its partners for. And I just wanted to know if the IMF views that as an acceptable rate? Whether this would be detrimental to the global economy. I know we have the WEO coming out in a few days. Just wanted to get your take on what’s unfolding right now.

    MS. KOZACK: Let us see if there’s any other questions on this topic before I answer. If anyone online wants to come in on this topic, please let us know.
    So let me start with where we are. Since April, when we think about the global economy, we see activity indicators that reflect a complex backdrop shaped by trade tensions. We also saw that in the first quarter of the year, the data showed some front-loading of exports and imports ahead of, at that time, what was expected tariff increases. The more recent data points to trade diversion and to some unwinding of the front-loading. And at the same time, we are seeing some trade deals. Some have lowered tariffs. And at the same time, there’s also been some deals or some, not deals, but we have seen increases in tariffs, for example, on steel, aluminum, and copper. So, our team is assessing all of this information as it is coming in. And they will put together a comprehensive picture, which we will talk about in the WEO next week.

    I would also just remind that when we released our WEO in April, we talked about a period of very high uncertainty. And at that time, we had in our WEO a reference forecast, right? And that reflected the fact that we were in an uncertain environment where there were many different paths forward. For example, we had an effective tariff rate of the U.S. of about 25 percent based on April 2nd announcements. That effective tariff rate for the U.S. declined to 14 percent based on the pause of April 9th. And of course, one of the important factors for assessing the impact of the deals on the U.S. economy and the global economy will be what is the new effective tariff rate that will prevail.
    So, all of that work is ongoing, and we will have a full assessment next week in the WEO.

    QUESTIONER: So, would the 15 to 20 percent rate be higher than what we saw in the April WEO?

    MS. KOZACK: I think the way I would answer that is to simply say that we are looking at all the deals in April, and we had an effective rate around 14 percent. There, of course, has been movement since April. There have been deals. There have been some reductions in some tariff rates. There have been increases in other tariff rates. So, the team is going to have to put together that comprehensive assessment to determine what would be the new effective tariff rate that would prevail. And then, we would be in a position to compare it to what we had based on the April 2 announcement, what we had based on the April 9 pause, and then where we are today.
    And another very important factor will be what is the overall impact on uncertainty, right? We have talked about being in a very highly uncertain environment. So, of course, we will be looking at that closely as well.

    QUESTIONER: The president of Ukraine recently signed a law that regulates the anti-corruption bodies in the country. How does the IMF view this law, and how can this impact IMF Ukraine cooperation moving forward? And secondly, Ukrainian Prime Minister Yulia Svyrydenko said Ukraine is facing a significant budget shortfall and is likely seeking a new IMF loan. What is the IMF’s assessment of the possibility of launching a new program?

    MS. KOZACK: Any other questions on Ukraine?

    QUESTIONER: I just wanted to follow up on whether, despite the moves by the Ukrainian government, can the IMF land to Ukraine?

    MS. KOZACK: Are there questions online on Ukraine? On Ukraine, let me just step back and remind kind of where we are with Ukraine.
    On June 30th, the IMF Board completed the Eighth Review of the EFF program and that enabled a disbursement of half a billion U.S. dollars. And that brought total disbursements under the program to U.S. $10.6 billion. Ukraine’s economy remains resilient. The authorities met, and this was reported as part of the Eighth Review, all of the end-March and continuous quantitative performance criteria; they met the prior action that was required for that review, and they also met two structural benchmarks.
    With respect to the specific questions, on the first question that you had, the enacted law, as we see it, neutralizes the effectiveness of Ukraine’s anti-corruption institutions. And from our perspective, that would be very problematic for macroeconomic stability and growth in Ukraine. Stepping back a bit, you know, the establishment and the development of independent institutions to detect and prosecute corruption cases has been central to the IMF’s engagement with Ukraine over the past 10 years. And these institutions have contributed to an improvement in governance in Ukraine over that period.
    Why is this important for Ukraine? From our perspective, Ukraine needs a robust anti-corruption architecture. And that will help level the playing field, improve the business climate, and attract private investment into Ukraine. And it’s a central piece of Ukraine’s reform agenda. So, from our perspective, safeguarding the independence of anti-corruption institutions remains a critical policy priority.
    We do take note of the government’s intention to introduce a new bill to restore the independence of the anti-corruption institutions.
    So, what I can say now is that in the coming weeks, the IMF Staff and the authorities are expected to intensify discussions about the 2026 budget and s to do an assessment of Ukraine’s financing needs, both for 2026 and over the medium term. They will be intensifying discussions to put together that comprehensive picture. That work is essential for the current program and any future potential engagement that we would have with Ukraine.

    QUESTIONER: If it finishes, what was the Staff assessment of the First Review of the agreement with Argentina and when would the Board’s definition be? And following the report on external reserves published this week, I think it was on Monday, does the IMF’s concerns continue?

    QUESTIONER: Has the Board already met to evaluate the First Review? And do you know if Argentina has requested a waiver? And how does the IMF assess the recent rate in this area, action rate and interest rates? And what are the causes of this change in monetary and exchange rate policy? Thank you.

    QUESTIONER: Yes, to add up to what was asked if there are any concerns regarding the impact of the exchange rates on inflation as well? And also, if the concerns remain regarding the weak external position for Argentina.

    QUESTIONER: President Milei has already confirmed that, for fiscal reasons, he will veto the laws recently passed by the Congress to increase pensions, extend the pension moratorium and declare an emergency disability. So, then has this intention being talked with the IMF previously or what is the IMF position on this matter?

    MS. KOZACK: On Argentina, here is what I can share today. So first, I want to mention that discussions on the First Review, which many of you have mentioned, are very advanced at this stage. And the next step in these discussions will be to reach a Staff-Level Agreement between the authorities and Staff. And we believe that that can happen very shortly. After the Staff-Level Agreement is reached, then Staff will present the documents to the Executive Board for their approval and consideration.
    What I can also add, and we have talked about that before here, is that the program has been off to a strong start. It has been underpinned by the continued implementation of tight macroeconomic policies, including a strong fiscal anchor and a tight monetary policy stance. The transition to a more flexible exchange rate regime has been smooth. Disinflation has resumed. And Argentina has reassessed international capital markets earlier than had been initially anticipated under the program.
    Given that our Staff and the authorities are very engaged in these discussions, which again are at an advanced stage, I’m not going to provide any further details now. We will give space for them to bring those discussions to a conclusion, and then we will, of course, communicate once those discussions have come to a conclusion. And again, we do think that a Staff-Level agreement could happen very, very shortly.

    QUESTIONER: Will the Board meeting be before, and start the holiday recess, or after? Because we are talking about 15 days, if not.

    MS. KOZACK: So right now, I don’t have any further details to share with you, but certainly once a Staff-Level Agreement is reached, we will be communicating, including the potential timing for formal Board discussion.

    QUESTIONER: Can you please kindly update us on the current status of the discussion between the IMF and the Republic of Senegal regarding the temporarily suspended disbursements? Especially with the Annual Meetings approaching in October in Washington, is there a realistic prospect of finalizing the matter before then? This is the first question.
    The second one, following the recent meeting between His Excellency, the President of the Republic of Senegal, Bassirou Diomaye Faye, and Mrs. Gita Gopinath, First Deputy Managing Director of the IMF, could you kindly also share some insight into the key topics discussed? What were the main points of their exchange, particularly in regard to economic and financial cooperation?

    MS. KOZACK: Any other questions on Senegal Online? Does anyone want to come in on Senegal?

    QUESTIONER: I have a follow-up because investors have been expecting the Board to consider the waiver by September. Is that timeline realistic? And the government also said it shared everything in its findings for reconciliation with the IMF. Does the Fund feel it has everything it needs in order to make the decision on the waiver?

    QUESTIONER: Have you received the report done by Mazars? And, is it enough to conclude the misreporting, and can we have maybe a time for the Board? And then, when can we expect also a new program?

    MS. KOZACK: So, let me turn to these questions.
    I’ll start by saying that the IMF remains closely engaged with Senegal. And as part of this process, as was noted, First Deputy Managing Director Gita Gopinath met with President Bassirou Faye during his visit to Washington, D.C. on July 9th. Our First Deputy Managing Director (FDMD), Gopinath, emphasized the IMF’s continued support, as Senegal works to resolve the misreporting matter. And the President reaffirmed his government’s strong commitment to transparency and reform.

    What I can also share is that an IMF Staff team will visit Dakar. The mission is tentatively planned for later in August. The purpose of the mission is going to be to discuss the steps needed to bring the misreporting case to our Executive Board. And the team will also use the opportunity to initiate discussions on the contours of a new IMF-supported program for Senegal. We are also working closely with the authorities to design the corrective actions aimed at addressing the root causes of the misreporting and, of course, to strengthen capacity development in Senegal.

    With respect to the questions on the report by Mazars, what I can share there is that we have received a preliminary debt inventory that has been prepared by Forvis Mazars. Our IMF Staff are currently reviewing that report and all the information in detail. The preliminary assessment in the report is broadly aligned with expectations, and the final validation is ongoing. And I will leave it at that on Senegal. That is what I can share for now.

    QUESTIONER: My question is on Japan. Last week, the upper house election in Japan was over, but still unclear on the composition of a new government. And what is it you are recommending? But almost all parties pledged fiscal — expansionary fiscal policies, from providing cash to reduction of consumption tax. And what is your recommendation to the new government, especially on fiscal policy, given the power of debt in Japan? And my second question is on monetary policy of Federal Reserve next week. And should the Federal Reserve cut interest rates preemptively under the circumstance of huge pressure from President Donald Trump.

    MS. KOZACK: Let us start with Japan. So maybe let me just step back a little bit to give an overview of how we assessed the Japanese economy in our April WEO.
    So, at that time, we expected growth to strengthen in Japan, and we expected inflation to converge to the Bank of Japan’s 2 percent target by 2027. Growth was projected to accelerate from 0.2 percent in 2024 to 0.6 percent this year. At the same time, and as has been the case for quite some time, Japan continues to have high levels of public debt. And because of that, our advice for Japan is for a clear fiscal consolidation plan to offset pressures from rising interest payments and also from aging-related spending. And because of this advice, we assess that Japan has limited fiscal space, again because of high public debt and these future spending needs.

    In the near term, our advice to Japan is that given this limited fiscal space, it is essential that any response to shocks, any fiscal response to shocks, is both temporary and also targeted. And by targeted, I mean targeted toward vulnerable households and firms that may be most affected by shocks. Generalized subsidies and tax cuts, in our view, should be avoided. And that is because they are not targeted to the most vulnerable, and they are not an efficient use of Japan’s limited fiscal space.

    And then, on your second question, what I can say about the U.S. economy is that the U.S. economy has proven to be resilient in the past few years. It is something that we have been talking about for quite some time. But we do see high-frequency data that indicate moderating domestic demand and low consumer and business sentiment in the U.S. In addition, and as we mentioned before, there was a strong front-loading of imports into the U.S. in the first quarter. And that, in anticipation of tariffs, and that led to an important drag on growth in the first quarter. At the same time, in the U.S., labor markets remain resilient, and the unemployment rate remains relatively low.

    With respect to inflation, we do see inflation on a path towards the Fed’s 2 percent target, but it is subject to upside risks. And that means that the Fed’s task is complex given the very highly uncertain economic environment. So the Fed will need to take into account both policies undertaken by the U.S. administration, as well as incoming data in, and of course, data on potential wage pressures as it comes to thinking about, you know, the extent of rate decisions and the timing of any rate decisions going forward.

    QUESTIONER: On Argentina, can the IMF confirm that there was a meeting on Tuesday between the Board and Staff regarding the first program review? And I know you said you wouldn’t be able to divulge much details, but I’m going to ask it anyway. When should you expect Argentina’s $2 billion disbursement?

    MS. KOZACK: So, on the first question, all I can say on this is that it’s not unusual for IMF Staff to informally brief the Executive Board on a broad range of issues. And on the timing of the disbursement, as I already indicated, we will provide more information on the timing for a formal Board meeting only once a Staff-Level Agreement has been reached. And that formal Board meeting would indicate the time when any disbursement would be made available to the Argentine authorities.

    QUESTIONER: First, let me say on behalf of my colleague from the U.S., around the world, as well as in Africa, to say thank you to Gita for everything that she has done. Our engagements with African journalists, especially. So that’s part of what I wanted to say, thank you to her. I know she’s leaving.
    And my question now goes to if you can provide updates on African nations. And I have two specific questions, one on Malawi and one on South Africa. The recent reports on Malawi said the country is facing macroeconomic challenges. I know in 2020 they received the completed HIPC program. Could you provide any updates on whether the country has reached out for any assistance regarding HIPC? Whether they qualify for another Heavily Indebted Poor Countries Initiative (HIPC) program to help them? We know in the past year, they’ve experienced floods, droughts, and natural issues that have affected the economy. I was wondering if the IMF is providing any assistance to them.
    The other question is on South Africa. We see growing tension between South Africa and the U.S. So, can you talk about if there’s any economic implication? South Africa is the largest economic in. Africa is also seen as a gateway to the continent. What are the macroeconomic issues, implications for the South African Development Community region (SADC), and also for the continent as a whole?

    MS. KOZACK: With respect to Malawi, what I can say is we completed the Article IV Consultation with Malawi just yesterday, July 22nd, 2025, or two days ago. So that was the 2025 Article IV Consultation that has been completed. And of course, there will be a lot of rich discussion of the state of the Malawian economy in that report. With respect to your more specific question on HIPC, what I can say is that Malawi completed the HIPC process in 2006. And at that time, Malawi secured U.S. $3.1 billion of debt relief through the HIPC Initiative and the Multilateral Debt Relief Initiative or otherwise known as MDRI. Since 2006, our assessment is that public debt in Malawi has returned to unsustainable levels. Total public debt is reached 88 percent of GDP at the end of 2024. And the interest bill on public debt is estimated to approach about 7 percent of GDP, which is quite high.

    We continue to urge the authorities to take decisive steps to restore public debt sustainability. Completing an external debt Restructuring and addressing the high cost of domestic borrowing are both essential to do this. And of course, strengthening public debt management and securing concessional financing will also be critical. So again, Malawi already completed the HIPC process in 2006.

    And then, on South Africa. What I can say about South Africa, I can talk a bit about how we see the outlook for South Africa, the economic outlook. So right now, based on the April WEO, we see the current economic outlook for South Africa as subdued. We projected growth in April at 1 percent for this year and 1.3 percent for next year. Uncertainty, including related to global trade policies, is weighing on activity in South Africa. And that it’s causing firms and households to delay their investment decisions and also consumption decisions.

    And I would also refer you to the April REO, Regional Economic Outlook, for Africa, and that includes some estimates on the impact of uncertainty and financial conditions on the Sub-Saharan Africa region.
    And finally, we of course continue to assess developments in South Africa, and we’ll be providing an update in the July WEO.

    QUESTIONER: I just had two follow-up questions. One was on your comments about the Fed. As you know, the tension between the Trump administration and the Fed, particularly Chair Powell, has been increasing lately. The President is going to go tour the Fed building that’s being renovated. It is a subject of controversy. Given that the IMF has been a stalwart defender of Central Bank independence, should any of this lead to Chair Powell’s replacement or his resignation? Just wondering, what kind of signal that would send to financial markets, to other countries, what kind of precedent would that set? And secondly, regarding First Deputy Managing Director Gopinath’s departure, can you walk us through the process for choosing a replacement for her?
    Traditionally, this has been a position that the U.S. has had a very strong hand in choosing. It has typically been an American. Do you expect the U.S. Treasury Department, for example, to basically recommend a candidate to the Managing Director?

    MS. KOZACK: On your first question for quite some time, the IMF has consistently advocated for Central Bank independence. And we’ve said it’s critical to ensuring that Central Banks are able to achieve their mandated objectives, such as low and stable inflation. And as we have seen through the disinflation process that has been taking place over the last few years, the credibility of Central Banks around the world has been instrumental in anchoring inflation expectations and in bringing down inflation across, you know, across the world. And across many countries in the world. And it is also important that independence, of course, it must coexist with clear accountability to the public.
    And on the question about the process, on Gita Gopinath’s decision to return to Harvard, maybe just to step back to say that on July 21st, you know, the Managing Director announced that Gita Gopinath, our First Deputy Managing Director, would be leaving the Fund at the end of August to return to Harvard University. She will be the inaugural Gregory and Ania Coffey Professor of Economics in the Department of Economics.

    And for your background, Ms. Gopinath joined the Fund in January 2019 as the first female Chief Economist of the Fund. And she was promoted to First Deputy Managing Director in January of 2022. I can add that this was a personal decision for Ms. Gopinath. She will return to her roots in academia, where she will continue to push the research frontier in international finance and macroeconomics. And she will also be training the next generation of economists.
    With respect to the selection of process and how the process works, the Managing Director selects and appoints the First Managing Director and the three Deputy Managing Directors of the Fund. The appointment is subject to approval by the Fund’s Executive Board. And in making the selection, the Managing Director consults with the Executive Board regarding the type of qualifications that, in the view of the Executive Board, a First Deputy Managing Director or a Deputy Managing Director should possess.

    QUESTIONER: My first question is regarding Sri Lanka. When can we expect the next review for the IMF-supported program? And secondly, given the uncertainties and risks that are currently opposing the economy for Sri Lanka, is there any decision or any exploration by the IMF to revisit some of the targets that have been implemented in the program that was given to Sri Lanka?

    QUESTIONER: I would like to know that now Sri Lanka has already finished four reviews, and now we are heading for the fifth one. What is the overall view of the IMF? That Sri Lanka’s performance, how we perform during these four reviews? And what are the expectations for the next review in brief? Thank you very much.

    MS. KOZACK: I have a question here that came in through the Press center on Sri Lanka. The question is what is the status of the IMF review of Sri Lanka’s program, an assessment of the macroeconomic outlook as well as the status of the review of the current mission that is visiting Sri Lanka. So, let me go ahead and take these. So, stepping back, on July 1st, the IMF’s Executive Board completed the Fourth Review under the EFF arrangement with Sri Lanka. This provided the country with U.S. $350 million to support its economic policies and reforms, and it brought total IMF financial support to U.S. $1.74 billion.

    What I can add is that Sri Lanka’s ambitious reform agenda continues to deliver commendable outcomes. Inflation remains low, revenue collection is improving and reserves, international reserves, continue to accumulate for the country. The post-crisis growth rebound to 5 percent in 2024 is quite remarkable. The revenue-to-GDP ratio improved from 8.2 percent in 2022 to 13.5 percent in 2024. The debt restructuring is nearly complete. And program performance has been generally strong overall, and the government remains committed to program objectives.

    What I can also add is that although the economic outlook remains positive for Sri Lanka, global trade policy and uncertainties do pose risks. And so, as the team moves forward to the Fifth Review, which we expect will be held in the fall, they will, of course, be looking at the overall and making an overall assessment of Sri Lanka’s economy. You know, including any implications from trade tensions or uncertainty. And of course, that will be — they will take that into account in discussions with the authorities on policies, and all of the program matters as part of the Fifth Review.

    QUESTIONER: Hi Julie. Thank you for taking my question. I have two questions, one on Syria and one on Egypt. So today there was the Saudi Syrian Investment Forum in Damascus, and it was said that in addition to the Saudi investments in support that there will be some global support on this. And the IFC was mentioned as well. So, what’s the IMF’s call on this, given that we have one of the G20 countries pledging this huge amount of investments in support? And how will the IMF contribute in this? That’s on Syria.

    And on Egypt, a few weeks ago in our press briefing here, it was mentioned that the two reviews, the Fifth and the Sixth, will be done together in the fall. Can we say that this is going to be in fall after the Annual Meeting, after the WEO report is published for the — for the region and for the global? And what, what is the main factor that we’re looking at here that would ultimately change the way it’s viewed, how Egypt’s economy is viewed in light of all the recent developments?

    MS. KOZACK: On Syria, what I can say is, and as we discussed here before, an IMF staff team did visit Syria from June 1st through 5th, and that was the first visit since 2009. The team was there to assess economic and financial conditions in Syria and to discuss with the authorities their economic policy and capacity building priorities, ultimately to support the recovery of the Syrian economy. With your specific question, what I can say there is that we have mentioned that Syria will need substantial international assistance to support the authorities’ efforts to rehabilitate the economy, meet urgent humanitarian needs, and rebuild essential institutions and infrastructure. And this not only includes concessional financial support, but it also extends to capacity development. And here, the IMF is committed to supporting Syria in its recovery efforts. The IMF Staff is working in coordination with other partners to develop a detailed roadmap for policy and capacity building priorities for some of the key economic institutions. So that’s kind of within our mandate, and that includes the Finance Ministry, the Central Bank, and the Statistics Agency.

    With respect to Egypt, what I can say on Egypt is that the IMF Staff conducted a mission to Cairo in May 2025. The mission noted continued progress under Egypt’s macroeconomic reform program, including improvements in inflation and foreign exchange reserves. However, additional time was needed to finalize key policy measures, particularly those related to reducing the state’s footprint in the economy by advancing the implementation of the state ownership policy and leveling the playing field for businesses. To allow for this continued work, the Fifth and Sixth Reviews under the EFF will be combined, and they are expected to be completed in the fall. Our team remains committed to supporting Egypt in advancing reforms to strengthen resilience and foster inclusive and private sector led growth.

    MS. KOZACK: Coming back to the Press Center, I have a question that has come in on Ghana. It says Ghana’s Finance Minister is presenting the mid-year budget today, following a first half marked by notable improvements in key economic indicators. However, concerns are rising about potential new fiscal slippages, and that could undermine gains in inflation control, currency stability, and overall recovery. Does the IMF share these concerns? And second question, what is your view on the role of monetary policy at this point, especially as the Bank of Ghana prepares to review its policy stance?

    Again, stepping back, on July 7th, the IMF’s Executive Board completed the Fourth Review of Ghana’s ECF arrangement. And after Board approval, Ghana received about U.S. $367 million, bringing total support to around U.S. $2.3 billion since May 2023.
    With respect to the budget here, I can say that the IMF has welcomed the government’s corrective actions, including a strong 2025 budget and an audit of payables to quantify and address the pre-election fiscal slippages. The authorities have recently implemented changes to their public financial management and public procurement acts, and this helps improve the overall fiscal responsibility framework in Ghana. And the authorities have also adopted a strategy to address issues in the energy sector. I can add that the mid-year budget review is fully in line with the parameters and objectives of the IMF-supported program.

    And with respect to the question on monetary policy, what I can say is that Ghana has made good progress since the beginning of the program in reducing inflation. Inflation was extremely high at the end of 2022 at 54 percent. It has now come down substantially to 14 percent at end June 2025. Going forward, it will be important for monetary policy to remain sufficiently tight, consistent with bringing inflation down to the Bank of Ghana’s target range, which is 8 percent plus or minus 2 percentage points.

    QUESTIONER: I’m going to ask about digital assets. One very specifically. There’s this controversy with El Salvador that is going around and around, but the government says they’re still buying Bitcoin, and it seems that the IMF is saying they are just moving things around between wallets. And I wanted you to address that. Also, with the passage here in the U.S. of the GENIUS Act, I guess, what does the IMF, what do they think the impacts of this sort of increasing legitimization of digital assets in the U.S. is going to be in terms of other economies, in terms of the ability to implement monetary policy? I just wonder if you have any comment on that. Thank you very much for taking the question.

    QUESTIONER: I have a question, specifically on El Salvador. How does the IMF assess the country’s continued Bitcoin accumulation in the context of the fiscal and transparency standards embedded in the Extended Fund Facility, the $1.4 billion program that was agreed last December? To what extent could this strategy complicate monitoring or risk management of this program?

    MS. KOZACK: So, on El Salvador, I’ll start with El Salvador and then Matthew, I’ll get to your question on the GENIUS Act. So again, stepping back. So, on June 27th, the IMF Executive Board completed El Salvador’s annual Article IV Consultation and concluded the First Review of the EFF that enabled El Salvador to have access to U.S. $118 million. And so far, $231 million has been disbursed under the EFF program that was approved in February.
    Program performance has been solid in El Salvador. The economy has continued to expand as macroeconomic imbalances are being addressed. The key fiscal and reserve targets were met at the time of the review with margins. And substantial progress continues with the ambitious reform agenda in the areas of governance, transparency, and financial resilience.
    And risks from Bitcoin continue to be mitigated. Regarding the questions on Bitcoin, I don’t have much new to say other than as we have stated in the past, the total amount of Bitcoin held across government-owned wallets remains unchanged, and that is consistent with El Salvador’s program commitments. The accumulation of Bitcoin by the Strategic Bitcoin Reserve Fund is consistent with program conditionality. And the increases in the Bitcoin Reserve Fund relate to movements across various government-owned wallets.
    And on your second question on the GENIUS Act, let me get to this one. Let me just step back for a moment, and then I’ll kind of come directly to the GENIUS Act.

    So, first, the GENIUS Act covers stablecoins, and stablecoins are a key type of privately issued crypto asset that aims to maintain a stable value. They do bring potential benefits, including cheaper and faster cross-border payments, increased financial inclusion, and greater portfolio diversification. So those are some of the potential benefits. There are operational risks, of course, associated with stablecoins if they are not properly regulated under an appropriate policy framework.

    Now, turning to the GENIUS Act. The GENIUS Act provides a comprehensive foundation for financial innovation and deepening. And that is balanced with consideration of consumer protection and market integrity goals and a clear identification of the institutional framework for oversight.
    Now, with respect to the kind of implications of the GENIUS Act, we, of course, are continuing to very actively monitor developments of stablecoins. We are assessing the potential implications of the GENIUS Act. And for us at the IMF, what is going to be especially important are going to be the implications for the international monetary system and the potential for spillovers to other jurisdictions. So that’s work that is ongoing, and our teams are making those assessments at this time.

    QUESTIONER: Any update on UAE economy outlook for GCC region and oil economy in general?

    MS. KOZACK: What I can share on UAE and the GCC in general, and I’ll be — and, of course, next week as part of the WEO update, we will, of course, be providing an update for the GCC region.
    So, starting with the UAE. Near-term growth in the UAE has been strong, and it is expected to remain healthy at over 4 percent in 2025. That was the assessment at the time of the April WEO. What we are seeing is robust growth in the non-hydrocarbon activity, and it is boosted by tourism, construction, public expenditure, and financial services. So those are the drivers of growth. Oil production is also increasing faster than expected, given the reversal of oil production cuts. And the UAE economy has demonstrated resilience to lower oil prices and increased oil price volatility this year.

    Now, turning to the GCC, what I can say for the GCC is that despite oil production cuts, GCC growth is estimated to have rebounded to 1.4 percent in 2024. And our projection at the time of the April WEO was that it will increase further to 3.3 percent in 2025. Non-hydrocarbon output growth is expected to remain strong, supported by rapid investment, construction, and accelerated reforms to diversify the GCC economies.
    Inflation remains low in the GCC, and our policy advice is for fiscal policy to remain prudent while strengthening fiscal reform implementation. And of course, we encourage policymakers in the region to continue reforms to support economic diversification. And as I noted, we will be providing an update of this assessment as part of the WEO update.
    And with that, I’m going to bring this Press Briefing to a close. Thank you all for your participation today.

    As a reminder, this briefing is embargoed until 11:00 A.M. Eastern Time in the United States. A transcript will be made available later on our website, IMF.org. Should you have any clarifications or additional queries, please do reach out to my colleagues via media@imf.org.

    This concludes our Press Briefing. I wish everyone a wonderful day, and I look forward to seeing you all next time.

    IMF Communications Department
    MEDIA RELATIONS

    PRESS OFFICER: Meera Louis

    Phone: +1 202 623-7100Email: MEDIA@IMF.org

    MIL OSI Economics

  • MIL-OSI USA: Under Cantwell Pressure, Admin Releases Critical Wildfire Funds

    US Senate News:

    Source: United States Senator for Washington Maria Cantwell

    07.24.25

    Under Cantwell Pressure, Admin Releases Critical Wildfire Funds

    Trump’s Office of Management and Budget had been withholding $20 million already allocated to WA state to prepare for and respond to wildfires

    WASHINGTON, D.C. — The federal Office of Management and Budget (OMB) has approved the Spend Plan for the over $280 million in overdue FY 2025 U.S. Forest Service State, Private and Tribal Forestry (SPTF) funding, including approximately $20 million for the Washington State Department of Natural Resources to use for firefighting training and equipment, forest management, and landscape restoration.

     

    “The State of Washington is in the middle of an active and dangerous wildfire season. After questioning the Chief of the Forest Service and the Secretary of Agriculture, I am pleased that Washington — and all states — are finally receiving the funding they need to prepare for and respond to wildfires this summer and in the future,” said U.S. Senator Maria Cantwell (D-WA), senior member of the Senate Committee on Energy and Natural Resources.

    “Thank you, Senator Cantwell, for your leadership in securing the release of fiscal year (FY) 2025 Forest Service funding for the State, Private, and Tribal Forestry programs,” said George Geissler, State Forester for Washington. “This critical funding was at risk of being included in a recission by the Trump Administration, but because of your efforts will now be put to work in support of forest health protection, private forest landowners, urban and community forests, and wildfire preparedness and response efforts across the State of Washington. On behalf of the Washington State Department of Natural Resources (DNR), we thank you for your tireless advocacy in support of our work.”

    SPTF funding is typically released to states months prior to the start of wildfire season to be used to train and equip state, local, and volunteer emergency responders and firefighters. This includes funding for fire academies, personal protection equipment, fire pumps, hoses, nozzles, and other safety gear. Delays risked the funding being rescinded by the Trump Administration and could degrade state and local efforts to prepare for and respond to wildfires this summer and in the future.

    On July 10, Sen. Cantwell questioned U.S. Forest Service Chief Tom Schultz about why the Trump Administration was withholding the SPTF funding.

    “It’s a budget that’s already been approved. So why aren’t we releasing the funds that go to the community so that they can best prepare for this fire season?” Sen. Cantwell asked during the July 10 Energy and Natural Resources Committee hearing.

    “We have not made a determination yet, but that’s something that is being evaluated,” Schultz responded. “We can’t commit that that’s for sure going to go out yet.”

    Video of Sen. Cantwell’s questioning of Schultz is HERE; a transcript is HERE.

    On July 16, Sen. Cantwell participated in a virtual briefing hosted by U.S. Secretary of Agriculture Brooke Rollins outlining the current wildfire situation and outlook across the western United States. During the briefing, she questioned Rollins on why OMB continued to withhold $280 million in SPTF funds.

    Nationally, state, local, and volunteer fire departments respond to roughly 80% of all wildfires each year. Last year DNR, along with local first responders, successfully kept over 93% of fires in Washington state at 10 acres or less. Funds from the SPTF can also be used for hazardous fuels work on non-federal land in the wildland urban interface (WUI), to recover land that has been burned, and for forest health management.

    The National Interagency Fire Center outlook predicts high wildfire risk across the entirety of Washington state from July through September 2025, and a high risk in Eastern and Central Washington in October. Six wildfires are currently burning in the state, and as of July 22, more than 37,000 acres have burned in the State of Washington this year.



    MIL OSI USA News

  • MIL-OSI: Montauk Renewables Schedules Second Quarter 2025 Conference Call for Thursday, August 7, 2025, at 8:30 a.m. ET

    Source: GlobeNewswire (MIL-OSI)

    PITTSBURGH, July 24, 2025 (GLOBE NEWSWIRE) — Montauk Renewables, Inc. (“Montauk” or “the Company”) (NASDAQ: MNTK), a renewable energy company specializing in the management, recovery and conversion of biogas into renewable natural gas (“RNG”), will host a conference call and webcast on Thursday, August 7, 2025, at 8:30 a.m. Eastern time to discuss its financial results for the second quarter ended June 30, 2025. The Company will issue a press release reporting the financial results after the close of regular stock market trading hours on the day prior to the conference call and webcast.

    Second Quarter 2025 Conference Call and Webcast Details

    Date:     Thursday, August 7, 2025
    Time:   8:30 a.m. ET
    Participant Access:   [Link Here]
       

    Please register for the conference call and webcast using the above link in advance of the call start time. The webcast platform will register your name and organization as well as provide dial-in numbers and a unique access pin. Please contact Gateway Group at (949) 574-3860 if you experience technical difficulties.

    The conference call and webcast will have a live Q&A session and be available here and on the Company’s website at https://ir.montaukrenewables.com.

    A replay of the conference call and webcast will be available after 11:30 a.m. Eastern time on the same day through August 7, 2026.

    About Montauk Renewables, Inc.

    Montauk Renewables, Inc. (NASDAQ: MNTK) is a renewable energy company specializing in the management, recovery and conversion of biogas into RNG. The Company captures methane, preventing it from being released into the atmosphere, and converts it into either RNG or electrical power for the electrical grid (“Renewable Electricity”). The Company, headquartered in Pittsburgh, Pennsylvania, has more than 30 years of experience in the development, operation and management of landfill methane-fueled renewable energy projects. The Company has operations at 13 projects and ongoing development projects located in California, Idaho, Ohio, Oklahoma, Pennsylvania, North Carolina, and Texas. The Company sells RNG and Renewable Electricity, taking advantage of Environmental Attribute premiums available under federal and state policies that incentivize their use. For more information, visit https://ir.montaukrenewables.com.

    Company Contact:

    John Ciroli
    Chief Legal Officer (CLO) & Secretary
    investors@montaukenergy.com
    (412) 747-8700

    Investor Relations Contact:

    Georg Venturatos
    Gateway Group
    MNTK@Gateway-grp.com
    (949) 574-3860

    The MIL Network

  • MIL-OSI: Montauk Renewables Schedules Second Quarter 2025 Conference Call for Thursday, August 7, 2025, at 8:30 a.m. ET

    Source: GlobeNewswire (MIL-OSI)

    PITTSBURGH, July 24, 2025 (GLOBE NEWSWIRE) — Montauk Renewables, Inc. (“Montauk” or “the Company”) (NASDAQ: MNTK), a renewable energy company specializing in the management, recovery and conversion of biogas into renewable natural gas (“RNG”), will host a conference call and webcast on Thursday, August 7, 2025, at 8:30 a.m. Eastern time to discuss its financial results for the second quarter ended June 30, 2025. The Company will issue a press release reporting the financial results after the close of regular stock market trading hours on the day prior to the conference call and webcast.

    Second Quarter 2025 Conference Call and Webcast Details

    Date:     Thursday, August 7, 2025
    Time:   8:30 a.m. ET
    Participant Access:   [Link Here]
       

    Please register for the conference call and webcast using the above link in advance of the call start time. The webcast platform will register your name and organization as well as provide dial-in numbers and a unique access pin. Please contact Gateway Group at (949) 574-3860 if you experience technical difficulties.

    The conference call and webcast will have a live Q&A session and be available here and on the Company’s website at https://ir.montaukrenewables.com.

    A replay of the conference call and webcast will be available after 11:30 a.m. Eastern time on the same day through August 7, 2026.

    About Montauk Renewables, Inc.

    Montauk Renewables, Inc. (NASDAQ: MNTK) is a renewable energy company specializing in the management, recovery and conversion of biogas into RNG. The Company captures methane, preventing it from being released into the atmosphere, and converts it into either RNG or electrical power for the electrical grid (“Renewable Electricity”). The Company, headquartered in Pittsburgh, Pennsylvania, has more than 30 years of experience in the development, operation and management of landfill methane-fueled renewable energy projects. The Company has operations at 13 projects and ongoing development projects located in California, Idaho, Ohio, Oklahoma, Pennsylvania, North Carolina, and Texas. The Company sells RNG and Renewable Electricity, taking advantage of Environmental Attribute premiums available under federal and state policies that incentivize their use. For more information, visit https://ir.montaukrenewables.com.

    Company Contact:

    John Ciroli
    Chief Legal Officer (CLO) & Secretary
    investors@montaukenergy.com
    (412) 747-8700

    Investor Relations Contact:

    Georg Venturatos
    Gateway Group
    MNTK@Gateway-grp.com
    (949) 574-3860

    The MIL Network

  • MIL-OSI: Cenovus to hold second-quarter 2025 conference call and webcast on July 31

    Source: GlobeNewswire (MIL-OSI)

    CALGARY, Alberta, July 24, 2025 (GLOBE NEWSWIRE) — Cenovus Energy Inc. (TSX:CVE) (NYSE:CVE) will release its second-quarter 2025 results on Thursday, July 31, 2025. The news release will provide consolidated second-quarter operating and financial information. The company’s financial statements will be available on Cenovus’s website, cenovus.com.

    Second-quarter 2025 conference call: 9 a.m. MT (11 a.m. ET)

    For analysts wanting to join the call, please register in advance.

    To participate, you must complete the online registration form in advance of the conference call start time. Register ahead of time to receive a unique PIN to access the conference call via telephone. Once registered, participants can dial into the conference call from their telephone via the unique PIN or click on the “Call Me” option to receive an automated call directly on their telephone.

    To listen to the conference call online, a live audio webcast will also be available and archived for approximately 30 days.

    Cenovus Energy Inc.

    Cenovus Energy Inc. is an integrated energy company with oil and natural gas production operations in Canada and the Asia Pacific region, and upgrading, refining and marketing operations in Canada and the United States. The company is committed to maximizing value by developing its assets in a safe, responsible and cost-efficient manner, integrating environmental, social and governance considerations into its business plans. Cenovus common shares and warrants are listed on the Toronto and New York stock exchanges, and the company’s preferred shares are listed on the Toronto Stock Exchange. For more information, visit cenovus.com.

    Find Cenovus on Facebook, LinkedIn, YouTube and Instagram.

    Cenovus contacts:

    Investors Media
    Investor Relations general line
    403-766-7711
    Media Relations general line
    403-766-7751

    The MIL Network